RE_615_Line Diff Relay Technical

Relion® Protection and Control

615 seriesTechnical Manual

Document ID: 1MRS756887Issued: 2013-03-04

Revision: GProduct version: 4.0 FP1

© Copyright 2013 ABB. All rights reserved

CopyrightThis document and parts thereof must not be reproduced or copied without writtenpermission from ABB, and the contents thereof must not be imparted to a thirdparty, nor used for any unauthorized purpose.

The software or hardware described in this document is furnished under a licenseand may be used, copied, or disclosed only in accordance with the terms of suchlicense.

TrademarksABB and Relion are registered trademarks of the ABB Group. All other brand orproduct names mentioned in this document may be trademarks or registeredtrademarks of their respective holders.

WarrantyPlease inquire about the terms of warranty from your nearest ABB representative.

http://www.abb.com/substationautomation

HTTP://WWW.ABB.COM/SUBSTATIONAUTOMATION

DisclaimerThe data, examples and diagrams in this manual are included solely for the conceptor product description and are not to be deemed as a statement of guaranteedproperties. All persons responsible for applying the equipment addressed in thismanual must satisfy themselves that each intended application is suitable andacceptable, including that any applicable safety or other operational requirementsare complied with. In particular, any risks in applications where a system failure and/or product failure would create a risk for harm to property or persons (including butnot limited to personal injuries or death) shall be the sole responsibility of theperson or entity applying the equipment, and those so responsible are herebyrequested to ensure that all measures are taken to exclude or mitigate such risks.

This document has been carefully checked by ABB but deviations cannot becompletely ruled out. In case any errors are detected, the reader is kindly requestedto notify the manufacturer. Other than under explicit contractual commitments, inno event shall ABB be responsible or liable for any loss or damage resulting fromthe use of this manual or the application of the equipment.

ConformityThis product complies with the directive of the Council of the EuropeanCommunities on the approximation of the laws of the Member States relating toelectromagnetic compatibility (EMC Directive 2004/108/EC) and concerningelectrical equipment for use within specified voltage limits (Low-voltage directive2006/95/EC). This conformity is the result of tests conducted by ABB inaccordance with the product standards EN 50263 and EN 60255-26 for the EMCdirective, and with the product standards EN 60255-1 and EN 60255-27 for the lowvoltage directive. The product is designed in accordance with the internationalstandards of the IEC 60255 series.

Table of contents

Section 1 Introduction.....................................................................23This manual......................................................................................23Intended audience............................................................................23Product documentation.....................................................................23

Product documentation set..........................................................23Document revision history...........................................................24Related documentation................................................................25

Symbols and conventions.................................................................25Symbols.......................................................................................25Document conventions................................................................25Functions, codes and symbols....................................................26

Section 2 615 series overview........................................................31Overview...........................................................................................31

Product series version history.....................................................32PCM600 and IED connectivity package version..........................34

Local HMI.........................................................................................34Display.........................................................................................35LEDs............................................................................................36Keypad........................................................................................36

Web HMI...........................................................................................37Authorization.....................................................................................38

Audit trail......................................................................................39Communication.................................................................................41

Ethernet redundancy...................................................................42

Section 3 Basic functions...............................................................45General parameters..........................................................................45Self-supervision................................................................................60

Internal faults...............................................................................60Warnings.....................................................................................62

LED indication control.......................................................................64Programmable LEDs........................................................................64

Function block.............................................................................64Functionality................................................................................64Signals.........................................................................................67Settings........................................................................................68Monitored data.............................................................................70

Time synchronization........................................................................71Parameter setting groups.................................................................72

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615 series 1Technical Manual

Function block.............................................................................72Functionality................................................................................72

Fault records.....................................................................................74Non-volatile memory.........................................................................78Binary input.......................................................................................79

Binary input filter time..................................................................79Binary input inversion..................................................................80Oscillation suppression................................................................80

RTD/mA inputs ................................................................................81Functionality................................................................................81Operation principle......................................................................81

Selection of input signal type..................................................81Selection of output value format.............................................81Input linear scaling.................................................................82Measurement chain supervision.............................................83Selfsupervision.......................................................................83Calibration..............................................................................83Limit value supervision...........................................................84Deadband supervision............................................................85RTD temperature vs. resistance.............................................86RTD/mA input connection......................................................87

Signals.........................................................................................89Settings........................................................................................89

GOOSE function blocks....................................................................92GOOSERCV_BIN function block.................................................92

Function block........................................................................92Functionality...........................................................................93Signals....................................................................................93

GOOSERCV_DP function block..................................................93Function block........................................................................93Functionality...........................................................................93Signals....................................................................................93

GOOSERCV_MV function block..................................................94Function block........................................................................94Functionality...........................................................................94Signals....................................................................................94

GOOSERCV_INT8 function block...............................................94Function block........................................................................94Functionality...........................................................................94Signals....................................................................................95

GOOSERCV_INTL function block...............................................95Function block........................................................................95Functionality...........................................................................95

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2 615 seriesTechnical Manual

Signals....................................................................................95GOOSERCV_CMV function block...............................................96


GOOSERCV_ENUM function block............................................97Function block........................................................................97Functionality...........................................................................97Signals....................................................................................97

GOOSERCV_INT32 function block.............................................97Function block........................................................................97Functionality...........................................................................97Signals....................................................................................98

Type conversion function blocks......................................................98QTY_GOOD function block.........................................................98


QTY_BAD function block.............................................................99Fucntion block........................................................................99Functionality...........................................................................99Signals....................................................................................99

QTY_GOOSE_COMM function block........................................100Functionality.........................................................................100Signals..................................................................................100

T_HEALTH function block.........................................................100Function block......................................................................100Functionality.........................................................................100Signals..................................................................................101

T_F32_INT8 function block........................................................101Function block......................................................................101Functionality.........................................................................101Signals..................................................................................101Settings................................................................................102

T_DIR function block.................................................................102Functionality.........................................................................102Signals..................................................................................102

Configurable logic blocks................................................................103Standard configurable logic blocks............................................103

OR function block.................................................................103AND function block...............................................................104XOR function block...............................................................105NOT function block...............................................................106

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MAX3 function block.............................................................107MIN3 function block..............................................................107R_TRIG function block.........................................................108F_TRIG function block..........................................................109T_POS_XX function blocks..................................................110SWITCHR function block......................................................111

Minimum pulse timer ................................................................112Minimum pulse timer TPGAPC............................................112Minimum pulse timer TPSGAPC..........................................113Minimum pulse timer TPMGAPC.........................................114

Pulse timer function block PTGAPC..........................................115Function block......................................................................115Functionality.........................................................................115Signals..................................................................................115Settings................................................................................116Technical data......................................................................116

Time-delay-off function block TOFGAPC..................................117Function block......................................................................117Functionality.........................................................................117Signals..................................................................................117Settings................................................................................118Technical data......................................................................118

Time-delay-on function block TONGAPC..................................119Function block......................................................................119Functionality.........................................................................119Signals..................................................................................119Settings................................................................................120Technical data......................................................................120

Set-reset function block SRGAPC.............................................121Function block......................................................................121Functionality.........................................................................121Signals..................................................................................122Settings................................................................................123

Move function block MVGAPC..................................................123Function block......................................................................123Functionality.........................................................................123Signals..................................................................................124

Local/remote control function block CONTROL........................124Function block......................................................................124Functionality.........................................................................124Signals..................................................................................125Settings................................................................................126Monitored data.....................................................................127

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Generic control points function block SPCGGIO.......................128Function block......................................................................128Functionality.........................................................................128Signals..................................................................................129Settings................................................................................130

Factory settings restoration............................................................132

Section 4 Protection functions......................................................133Three-phase current protection......................................................133

Three-phase non-directional overcurrent protectionPHxPTOC..................................................................................133

Identification.........................................................................133Function block......................................................................133Functionality.........................................................................133Operation principle...............................................................134Measurement modes............................................................136Timer characteristics............................................................137Application............................................................................138Signals..................................................................................145Settings................................................................................146Monitored data.....................................................................149Technical data......................................................................150Technical revision history.....................................................150

Three-phase directional overcurrent protectionDPHxPDOC...............................................................................151

Identification.........................................................................151Function block......................................................................151Functionality.........................................................................151Operation principle ..............................................................152Measurement modes............................................................157Directional overcurrent characteristics ................................157Application............................................................................165Signals..................................................................................167Settings................................................................................169Monitored data.....................................................................172Technical data......................................................................173Technical revision history.....................................................174

Three-phase thermal protection for feeders, cables anddistribution transformers T1PTTR.............................................174

Identification.........................................................................174Function block......................................................................175Functionality.........................................................................175Operation principle...............................................................175Application............................................................................178

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Signals..................................................................................179Settings................................................................................179Monitored data.....................................................................180Technical data......................................................................180Technical revision history.....................................................181

Three-phase thermal overload protection for powertransformers, two time constants T2PTTR................................181

Identification.........................................................................181Function block......................................................................181Functionality.........................................................................181Operation principle...............................................................182Application............................................................................185Signals..................................................................................187Settings................................................................................188Monitored data.....................................................................188Technical data......................................................................189Technical revision history.....................................................189

Motor load jam protection JAMPTOC........................................189Identification.........................................................................189Function block......................................................................189Functionality.........................................................................189Operation principle...............................................................190Application............................................................................191Signals..................................................................................191Settings................................................................................192Monitored data.....................................................................192Technical data......................................................................192

Loss of load supervision LOFLPTUC........................................193Identification.........................................................................193Function block......................................................................193Functionality.........................................................................193Operation principle...............................................................193Application............................................................................194Signals..................................................................................195Settings................................................................................195Monitored data.....................................................................195Technical data......................................................................196

Thermal overload protection for motors MPTTR.......................196Identification.........................................................................196Function block......................................................................196Functionality.........................................................................196Operation principle...............................................................197Application............................................................................205

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Signals..................................................................................209Settings................................................................................210Monitored data.....................................................................211Technical data......................................................................211Technical revision history.....................................................211

Earth-fault protection......................................................................212Non-directional earth-fault protection EFxPTOC.......................212

Identification.........................................................................212Function block......................................................................212Functionality.........................................................................212Operation principle...............................................................213Measurement modes............................................................214Timer characteristics............................................................215Application............................................................................216Signals..................................................................................217Settings................................................................................218Monitored data.....................................................................220Technical data......................................................................221Technical revision history.....................................................221

Directional earth-fault protection DEFxPDEF............................222Identification.........................................................................222Function block......................................................................222Functionality.........................................................................223Operation principle...............................................................223Directional earth-fault principles...........................................228Measurement modes............................................................234Timer characteristics............................................................235Directional earth-fault characteristics...................................236Application............................................................................244Signals..................................................................................246Settings................................................................................247Monitored data.....................................................................250Technical data......................................................................251Technical revision history.....................................................252

Transient/intermittent earth-fault protection INTRPTEF............253Identification.........................................................................253Function block......................................................................253Functionality.........................................................................253Operation principle...............................................................254Application............................................................................256Signals..................................................................................258Settings................................................................................258Monitored data.....................................................................259

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Technical data......................................................................259Technical revision history.....................................................260

Admittance-based earth-fault protection EFPADM....................260Identification.........................................................................260Function block......................................................................260Functionality.........................................................................260Operation principle...............................................................261Neutral admittance characteristics.......................................273Application............................................................................279Signals..................................................................................283Settings................................................................................284Monitored data.....................................................................285Technical data......................................................................285

Harmonic based earth-fault protection HAEFPTOC..................285Identification.........................................................................285Function block......................................................................286HAEFPTOC functionality......................................................286Operation principle...............................................................286Application............................................................................290Signals..................................................................................291Settings................................................................................292Monitored data.....................................................................293Technical data......................................................................293

Wattmetric earth-fault protection WPWDE................................293Identification.........................................................................293Function block......................................................................294Functionality.........................................................................294Operation principle...............................................................294Timer characteristics............................................................299Measurement modes............................................................301Application............................................................................301Signals..................................................................................304Settings................................................................................304Monitored data.....................................................................305Technical data......................................................................305

Differential protection......................................................................306Line differential protection and related measurements,stabilized and instantaneous stages LNPLDF...........................306

Identification.........................................................................306Function block......................................................................306Functionality.........................................................................306Operation principle...............................................................307Commissioning.....................................................................317

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Application............................................................................323Signals..................................................................................328Settings................................................................................329Monitored Data.....................................................................330Technical data......................................................................331Technical revision history.....................................................332

Stabilized and instantaneous differential protection for 2W-transformers TR2PTDF.............................................................332

Identification.........................................................................332Function block......................................................................332Functionality.........................................................................332Operation principle...............................................................333Application............................................................................346CT connections and transformation ratio correction.............361Signals..................................................................................365Settings................................................................................366Monitored data.....................................................................368Technical data......................................................................370

Numerically stabilized low-impedance restricted earth-faultprotection LREFPNDF...............................................................370

Identification.........................................................................370Function block......................................................................371Functionality.........................................................................371Operation principle...............................................................371Application............................................................................375Signals..................................................................................378Settings................................................................................378Monitored data.....................................................................379Technical data......................................................................379

High-impedance-based restricted earth-fault protectionHREFPDIF.................................................................................379

Identification.........................................................................379Function block......................................................................380Functionality.........................................................................380Operation principle...............................................................380Application............................................................................381The measuring configuration................................................384Recommendations for current transformers ........................385Setting examples..................................................................389Signals..................................................................................392Settings................................................................................393Monitored data.....................................................................393Technical data......................................................................393

Unbalance protection......................................................................394

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Negative-sequence overcurrent protection NSPTOC................394Identification.........................................................................394Function block......................................................................394Functionality.........................................................................394Operation principle...............................................................395Application............................................................................397Signals..................................................................................397Settings................................................................................398Monitored data.....................................................................399Technical data......................................................................399Technical revision history.....................................................399

Phase discontinuity protection PDNSPTOC..............................400Identification.........................................................................400Function block......................................................................400Functionality.........................................................................400Operation principle...............................................................400Application............................................................................402Signals..................................................................................403Settings................................................................................403Monitored data.....................................................................404Technical data......................................................................404

Phase reversal protection PREVPTOC.....................................404Identification.........................................................................404Function block......................................................................405Functionality.........................................................................405Operation principle...............................................................405Application............................................................................406Signals..................................................................................406Settings................................................................................406Monitored data.....................................................................407Technical data......................................................................407

Negative-sequence overcurrent protection for motorsMNSPTOC.................................................................................407

Identification.........................................................................407Function block......................................................................408Functionality.........................................................................408Operation principle...............................................................408Timer characteristics............................................................409Application............................................................................411Signals..................................................................................412Settings................................................................................412Monitored data.....................................................................413Technical data......................................................................413

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Voltage protection...........................................................................414Three-phase overvoltage protection PHPTOV..........................414

Identification.........................................................................414Function block......................................................................414Functionality.........................................................................414Operation principle...............................................................414Timer characteristics............................................................418Application............................................................................418Signals..................................................................................419Settings................................................................................420Monitored data.....................................................................421Technical data......................................................................421Technical revision history.....................................................421

Three-phase undervoltage protection PHPTUV........................422Identification.........................................................................422Function block......................................................................422Functionality.........................................................................422Operation principle...............................................................422Timer characteristics............................................................426Application............................................................................426Signals..................................................................................427Settings................................................................................427Monitored data.....................................................................428Technical data......................................................................429Technical revision history.....................................................429

Residual overvoltage protection ROVPTOV..............................429Identification.........................................................................429Function block......................................................................429Functionality.........................................................................430Operation principle...............................................................430Application............................................................................431Signals..................................................................................431Settings................................................................................432Monitored data.....................................................................432Technical data......................................................................432Technical revision history.....................................................433

Negative-sequence overvoltage protection NSPTOV...............433Identification.........................................................................433Function block......................................................................433Functionality.........................................................................433Operation principle...............................................................434Application............................................................................435Signals..................................................................................435

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Settings................................................................................436Monitored data.....................................................................436Technical data......................................................................436Technical revision history.....................................................437

Positive-sequence undervoltage protection PSPTUV...............437Identification.........................................................................437Function block......................................................................437Functionality.........................................................................437Operation principle...............................................................438Application............................................................................439Signals..................................................................................440Settings................................................................................440Monitored data.....................................................................441Technical data......................................................................441Technical revision history.....................................................441

Frequency protection......................................................................442Frequency protection FRPFRQ.................................................442

Identification.........................................................................442Function block......................................................................442Functionality.........................................................................442Operation principle...............................................................442Application............................................................................448Signals..................................................................................449Settings................................................................................449Monitored data.....................................................................450Technical data......................................................................450

Load shedding and restoration LSHDPFRQ.............................450Identification.........................................................................450Function block......................................................................451Functionality.........................................................................451Operation principle...............................................................451Application............................................................................456Signals..................................................................................460Settings................................................................................460Monitored data.....................................................................461Technical data......................................................................461

Arc protection ARCSARC...............................................................462Identification..............................................................................462Function block...........................................................................462Functionality..............................................................................462Operation principle....................................................................462Application.................................................................................464Signals.......................................................................................467

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Settings......................................................................................468Monitored data...........................................................................468Technical data...........................................................................468

Motor startup supervision STTPMSU.............................................469Identification..............................................................................469Function block...........................................................................469Functionality..............................................................................469Operation principle....................................................................470Application.................................................................................475Signals.......................................................................................478Settings......................................................................................479Monitored data...........................................................................479Technical data...........................................................................480

Multipurpose protection MAPGAPC...............................................480Identification..............................................................................480Function block...........................................................................481Functionality..............................................................................481Operation principle....................................................................481Application.................................................................................483Signals.......................................................................................483Settings......................................................................................483Monitored data...........................................................................484Technical data...........................................................................484

Section 5 Protection related functions..........................................485Three-phase inrush detector INRPHAR.........................................485

Identification..............................................................................485Function block...........................................................................485Functionality..............................................................................485Operation principle....................................................................485Application.................................................................................487Signals.......................................................................................488Settings......................................................................................488Monitored data...........................................................................489Technical data...........................................................................489

Circuit breaker failure protection CCBRBRF..................................489Identification..............................................................................489Function block...........................................................................489Functionality..............................................................................490Operation principle....................................................................490Application.................................................................................496Signals.......................................................................................498Settings......................................................................................498Monitored data...........................................................................499

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Technical data...........................................................................499Technical revision history..........................................................499

Master trip TRPPTRC.....................................................................499Identification..............................................................................499Function block...........................................................................500Functionality..............................................................................500Operation principle....................................................................500Application.................................................................................501Signals.......................................................................................502Settings......................................................................................503Monitored data...........................................................................503Technical revision history..........................................................503

Binary signal transfer BSTGGIO....................................................503Identification..............................................................................503Function block...........................................................................504Functionality..............................................................................504Operation principle....................................................................504Application.................................................................................505Signals.......................................................................................507Settings......................................................................................507Technical data...........................................................................508

Emergency startup ESMGAPC......................................................508Identification..............................................................................508Function block...........................................................................509Functionality..............................................................................509Operation principle....................................................................509Application.................................................................................510Signals.......................................................................................510Settings......................................................................................511Monitored data...........................................................................511Technical data...........................................................................511

Section 6 Supervision functions...................................................513Trip circuit supervision TCSSCBR..................................................513

Identification..............................................................................513Function block...........................................................................513Functionality .............................................................................513Operation principle....................................................................513Application.................................................................................514Signals.......................................................................................521Settings......................................................................................521Monitored data...........................................................................522

Current circuit supervision CCRDIF...............................................522Identification..............................................................................522

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Function block...........................................................................522Functionality..............................................................................522Operation principle....................................................................523Application.................................................................................525Signals.......................................................................................529Settings......................................................................................530Monitored data...........................................................................530Technical data...........................................................................530

Protection communication supervision PCSRTPC.........................530Identification..............................................................................530Function block...........................................................................531Functionality..............................................................................531Operation principle....................................................................532Application.................................................................................533Signals.......................................................................................534Settings......................................................................................534Monitored data...........................................................................534Technical revision history..........................................................535

Fuse failure supervision SEQRFUF...............................................535Identification..............................................................................535Function block...........................................................................535Functionality..............................................................................535Operation principle....................................................................536Application.................................................................................539Signals.......................................................................................540Settings......................................................................................540Monitored data...........................................................................541Technical data...........................................................................541

Operation time counter MDSOPT...................................................541Identification..............................................................................541Function block...........................................................................542Functionality..............................................................................542Operation principle....................................................................542Application.................................................................................543Signals.......................................................................................544Settings......................................................................................544Monitored data...........................................................................544Technical data...........................................................................545

Section 7 Condition monitoring functions.....................................547Circuit breaker condition monitoring SSCBR..................................547

Identification..............................................................................547Function block...........................................................................547Functionality..............................................................................547

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Operation principle....................................................................548Circuit breaker status...........................................................549Circuit breaker operation monitoring....................................549Breaker contact travel time...................................................550Operation counter.................................................................551Accumulation of Iyt................................................................552Remaining life of circuit breaker...........................................553Circuit breaker spring-charged indication.............................555Gas pressure supervision.....................................................555

Application.................................................................................556Signals.......................................................................................559Settings......................................................................................560Monitored data...........................................................................562Technical data...........................................................................562Technical revision history..........................................................563

Section 8 Measurement functions................................................565Basic measurements......................................................................565

Functions...................................................................................565Measurement functionality.........................................................566Measurement function applications...........................................573Three-phase current measurement CMMXU............................573

Identification.........................................................................573Function block......................................................................574Signals..................................................................................574Settings................................................................................574Monitored data.....................................................................575Technical data......................................................................575Technical revision history.....................................................576

Three-phase voltage measurement VMMXU............................576Identification.........................................................................576Function block......................................................................576Signals..................................................................................576Settings................................................................................577Monitored data.....................................................................577Technical data......................................................................577

Residual current measurement RESCMMXU...........................578Identification.........................................................................578Function block......................................................................578Signals..................................................................................578Settings................................................................................578Monitored data.....................................................................579Technical data......................................................................579Technical revision history.....................................................579

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Residual voltage measurement RESVMMXU...........................579Identification.........................................................................579Function block......................................................................580Signals..................................................................................580Settings................................................................................580Monitored data.....................................................................580Technical data......................................................................581Technical revision history.....................................................581

Frequency measurement FMMXU............................................581Identification.........................................................................581Function block......................................................................581Signals..................................................................................581Settings................................................................................582Monitored data.....................................................................582Technical data......................................................................582

Sequence current measurement CSMSQI................................582Identification.........................................................................582Function block......................................................................582Signals..................................................................................583Settings................................................................................583Monitored data.....................................................................584Technical data......................................................................584

Sequence voltage measurement VSMSQI................................584Identification.........................................................................584Function block......................................................................585Signals..................................................................................585Settings................................................................................585Monitored data.....................................................................586Technical data......................................................................586

Three-phase power and energy measurement PEMMXU.........586Identification.........................................................................586Function block......................................................................587Signals..................................................................................587Settings................................................................................587Monitored data.....................................................................588Technical data......................................................................588

Disturbance recorder......................................................................589Functionality..............................................................................589

Recorded analog inputs.......................................................589Triggering alternatives..........................................................589Length of recordings.............................................................591Sampling frequencies...........................................................591Uploading of recordings.......................................................592

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Deletion of recordings..........................................................592Storage mode.......................................................................593Pre-trigger and post-trigger data..........................................593Operation modes..................................................................593Exclusion mode....................................................................594

Configuration.............................................................................594Application.................................................................................595Settings......................................................................................596Monitored data...........................................................................599Technical revision history..........................................................599

Tap changer position indicator TPOSSLTC...................................599Identification..............................................................................599Function block...........................................................................600Functionality..............................................................................600Operation principle....................................................................600Application.................................................................................603Signals.......................................................................................604Settings......................................................................................604Monitored data...........................................................................604Technical data...........................................................................604Technical revision history..........................................................604

Section 9 Control functions..........................................................605Circuit breaker control CBXCBR, Disconnector controlDCXSWI and Earthing switch control ESXSWI .............................605

Identification..............................................................................605Function block...........................................................................605Functionality..............................................................................606Operation principle....................................................................606Application.................................................................................609Signals.......................................................................................610Settings......................................................................................612Monitored data...........................................................................613Technical revision history..........................................................614

Disconnector position indicator DCSXSWI and earthing switchindication ESSXSWI.......................................................................614

Identification..............................................................................614Function block...........................................................................614Functionality..............................................................................615Operation principle....................................................................615Application.................................................................................615Signals.......................................................................................615Settings......................................................................................616Monitored data...........................................................................616

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Synchronism and energizing check SECRSYN.............................617Identification..............................................................................617Function block...........................................................................617Functionality..............................................................................617Operation principle....................................................................618Application.................................................................................625Signals.......................................................................................627Settings......................................................................................628Monitored data...........................................................................629Technical data...........................................................................629

Autoreclosing DARREC..................................................................630Identification..............................................................................630Function block...........................................................................630Functionality..............................................................................630

Protection signal definition...................................................631Zone coordination.................................................................631Master and slave scheme....................................................632Thermal overload blocking...................................................632

Operation principle....................................................................633Signal collection and delay logic..........................................633Shot initiation........................................................................637Shot pointer controller..........................................................640Reclose controller.................................................................641Sequence controller.............................................................643Protection coordination controller.........................................644Circuit breaker controller......................................................645

Counters....................................................................................646Application.................................................................................647

Shot initiation........................................................................648Sequence.............................................................................652Configuration examples........................................................653Delayed initiation lines..........................................................656Shot initiation from protection start signal............................658Fast trip in Switch on to fault................................................658

Signals.......................................................................................659Settings......................................................................................660Monitored data...........................................................................662Technical data...........................................................................663Technical revision history..........................................................664

Tap changer control with voltage regulator OLATCC.....................664Identification..............................................................................664Function block...........................................................................664Functionality..............................................................................664

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Operation principle....................................................................665Voltage and current measurements..........................................666Tap changer position inputs......................................................667Operation mode selection..........................................................668Manual voltage regulation.........................................................669Automatic voltage regulation of single transformer...................670Automatic voltage regulation of parallel transformers...............674

Master/Follower principle M/F..............................................675Negative Reactance Principle NRP......................................677Minimizing Circulating Current principle MCC......................679

Timer characteristics.................................................................681Pulse control..............................................................................683Blocking scheme.......................................................................684Alarm indication.........................................................................688Application.................................................................................689Signals.......................................................................................696Settings......................................................................................697Monitored data...........................................................................698Technical data...........................................................................700Technical revision history..........................................................701

Section 10 Power quality measurement functions.........................703Current total demand distortion monitoring CMHAI........................703

Identification..............................................................................703Function block...........................................................................703Functionality..............................................................................703Operation principle....................................................................703Application.................................................................................704Signals.......................................................................................705Settings......................................................................................706Monitored data...........................................................................706

Voltage total harmonic distortion monitoring VMHAI......................707Identification..............................................................................707Function block...........................................................................707Functionality..............................................................................707Operation principle....................................................................707Application.................................................................................708Signals.......................................................................................708Settings......................................................................................709Monitored data...........................................................................709

Voltage variation PHQVVR.............................................................710Identification..............................................................................710Function block...........................................................................710Functionality..............................................................................710

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Operation principle....................................................................711Phase mode setting..............................................................711Variation detection................................................................712Variation validation...............................................................713Duration measurement.........................................................716Three/single-phase selection variation examples................717

Recorded data...........................................................................719Application.................................................................................721Signals.......................................................................................723Settings......................................................................................724Monitored data...........................................................................725

Section 11 General function block features....................................729Definite time characteristics............................................................729

Definite time operation...............................................................729Current based inverse definite minimum time characteristics........732

IDMT curves for overcurrent protection.....................................732Standard inverse-time characteristics..................................736User-programmable inverse-time characteristics.................751RI and RD-type inverse-time characteristics........................751

Reset in inverse-time modes.....................................................755Inverse-timer freezing................................................................764

Voltage based inverse definite minimum time characteristics........765IDMT curves for overvoltage protection.....................................765

Standard inverse-time characteristics for overvoltageprotection..............................................................................767User programmable inverse-time characteristics forovervoltage protection..........................................................771IDMT curve saturation of overvoltage protection..................772

IDMT curves for undervoltage protection..................................772Standard inverse-time characteristics for undervoltageprotection..............................................................................773User-programmable inverse-time characteristics forundervoltage protection........................................................775IDMT curve saturation of undervoltage protection...............776

Frequency measurement and protection........................................776Measurement modes......................................................................777Calculated measurements..............................................................779

Section 12 Requirements for measurement transformers..............781Current transformers......................................................................781

Current transformer requirements for non-directionalovercurrent protection................................................................781

Current transformer accuracy class and accuracy limitfactor....................................................................................781

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Non-directional overcurrent protection.................................782Example for non-directional overcurrent protection..............783

Section 13 IED physical connections.............................................785Protective earth connections..........................................................785Binary and analog connections......................................................785Communication connections..........................................................786

Ethernet RJ-45 front connection................................................786Ethernet rear connections.........................................................787EIA-232 serial rear connection..................................................787EIA-485 serial rear connection..................................................787Line differential protection communication connection..............788Optical ST serial rear connection..............................................788Communication interfaces and protocols..................................788Rear communication modules...................................................789

COM0001-COM0014 jumper locations and connections.....793COM0023 jumper locations and connections.......................796COM0008 and COM0010 jumper locations andconnections..........................................................................801COM0032-COM0034 jumper locations and connections.....804

Recommended third-party industrial Ethernet switches ...........807

Section 14 Technical data..............................................................809

Section 15 IED and functionality tests............................................815

Section 16 Applicable standards and regulations..........................819

Section 17 Glossary.......................................................................821

Table of contents


Section 1 Introduction

1.1 This manual

The technical manual contains application and functionality descriptions and listsfunction blocks, logic diagrams, input and output signals, setting parameters andtechnical data sorted per function. The manual can be used as a technical referenceduring the engineering phase, installation and commissioning phase, and duringnormal service.

1.2 Intended audience

This manual addresses system engineers and installation and commissioningpersonnel, who use technical data during engineering, installation andcommissioning, and in normal service.

The system engineer must have a thorough knowledge of protection systems,protection equipment, protection functions and the configured functional logic inthe IEDs. The installation and commissioning personnel must have a basicknowledge in handling electronic equipment.

1.3 Product documentation

1.3.1 Product documentation setThe application manual contains application descriptions and setting guidelinessorted per function. The manual can be used to find out when and for what purposea typical protection function can be used. The manual can also be used whencalculating settings.

The communication protocol manual describes a communication protocolsupported by the IED. The manual concentrates on vendor-specific implementations.

The engineering guide provides information for IEC 61850 engineering of theprotection IEDs with PCM600 and IET600. This guide concentrates especially onthe configuration of GOOSE communication with these tools. The guide can beused as a technical reference during the engineering phase, installation andcommissioning phase, and during normal service. For more details on tool usage,see the PCM600 documentation.

1MRS756887 G Section 1Introduction


The engineering manual contains instructions on how to engineer the IEDs usingthe different tools in PCM600. The manual provides instructions on how to set up aPCM600 project and insert IEDs to the project structure. The manual alsorecommends a sequence for engineering of protection and control functions, LHMIfunctions as well as communication engineering for IEC 61850 and othersupported protocols.

The installation manual contains instructions on how to install the IED. Themanual provides procedures for mechanical and electrical installation. The chaptersare organized in chronological order in which the IED should be installed.

The operation manual contains instructions on how to operate the IED once it hasbeen commissioned. The manual provides instructions for monitoring, controllingand setting the IED. The manual also describes how to identify disturbances andhow to view calculated and measured power grid data to determine the cause of afault.

The point list manual describes the outlook and properties of the data pointsspecific to the IED. The manual should be used in conjunction with thecorresponding communication protocol manual.

The technical manual contains application and functionality descriptions and listsfunction blocks, logic diagrams, input and output signals, setting parameters andtechnical data sorted per function. The manual can be used as a technical referenceduring the engineering phase, installation and commissioning phase, and duringnormal service.

1.3.2 Document revision historyDocument revision/date Product series version HistoryA/2009-07-03 2.0 First release

B/2009-12-02 2.0 Content updated

C/2010-06-11 3.0 Content updated to correspond to theproduct series version

D/2010-06-29 3.0 Terminology updated

E/2010-09-24 3.0 Content updated

F/2012-05-11 4.0 Content updated to correspond to theproduct series version

G/2013-03-04 4.0 FP1 Content updated to correspond to theproduct series version

Download the latest documents from the ABB Websitehttp://www.abb.com/substationautomation.

Section 1 1MRS756887 GIntroduction



1.3.3 Related documentationProduct series- and product-specific manuals can be downloaded from the ABBWebsite http://www.abb.com/substationautomation.

1.4 Symbols and conventions

1.4.1 Symbols

The electrical warning icon indicates the presence of a hazardwhich could result in electrical shock.

The warning icon indicates the presence of a hazard which couldresult in personal injury.

The caution icon indicates important information or warning relatedto the concept discussed in the text. It might indicate the presenceof a hazard which could result in corruption of software or damageto equipment or property.

The information icon alerts the reader of important facts andconditions.

The tip icon indicates advice on, for example, how to design yourproject or how to use a certain function.

Although warning hazards are related to personal injury, it is necessary tounderstand that under certain operational conditions, operation of damagedequipment may result in degraded process performance leading to personal injuryor death. Therefore, comply fully with all warning and caution notices.

1.4.2 Document conventionsA particular convention may not be used in this manual.

• Abbreviations and acronyms in this manual are spelled out in the glossary. Theglossary also contains definitions of important terms.

• Push-button navigation in the LHMI menu structure is presented by using thepush-button icons.




To navigate between the options, use and .• HMI menu paths are presented in bold.

Select Main menu/Settings.• LHMI messages are shown in Courier font.

To save the changes in non-volatile memory, select Yes and press .• Parameter names are shown in italics.

The function can be enabled and disabled with the Operation setting.• Parameter values are indicated with quotation marks.

The corresponding parameter values are "On" and "Off".• IED input/output messages and monitored data names are shown in Courier font.

When the function starts, the START output is set to TRUE.

1.4.3 Functions, codes and symbolsAll available functions are listed in the table. All of them may not be applicable toall products.

Table 1: Functions included in standard configurations

Function IEC 61850 IEC 60617 IEC-ANSIProtection

Three-phase non-directionalovercurrent protection, low stage

PHLPTOC1 3I> (1) 51P-1 (1)

PHLPTOC2 3I> (2) 51P-1 (2)

Three-phase non-directionalovercurrent protection, high stage

PHHPTOC1 3I>> (1) 51P-2 (1)

PHHPTOC2 3I>> (2) 51P-2 (2)

Three-phase non-directionalovercurrent protection, instantaneousstage

PHIPTOC1 3I>>> (1) 50P/51P (1)

PHIPTOC2 3I>>> (2) 50P/51P (2)

Three-phase directional overcurrentprotection, low stage

DPHLPDOC1 3I> → (1) 67-1 (1)

DPHLPDOC2 3I> → (2) 67-1 (2)

Three-phase directional overcurrentprotection, high stage DPHHPDOC1 3I>> → 67-2

Non-directional earth-fault protection,low stage

EFLPTOC1 I0> (1) 51N-1 (1)

EFLPTOC2 I0> (2) 51N-1 (2)

Non-directional earth-fault protection,high stage

EFHPTOC1 I0>> (1) 51N-2 (1)

EFHPTOC2 I0>> (2) 51N-2 (2)

Non-directional earth-fault protection,instantaneous stage EFIPTOC1 I0>>> 50N/51N

Directional earth-fault protection, lowstage

DEFLPDEF1 I0> →(1) 67N-1 (1)

DEFLPDEF2 I0> → (2) 67N-1 (2)

Directional earth-fault protection,high stage DEFHPDEF1 I0>> → 67N-2

Table continues on next page



Function IEC 61850 IEC 60617 IEC-ANSIAdmittance based earth-faultprotection1)

EFPADM1 Y0> → (1) 21YN (1)

EFPADM2 Y0> → (2) 21YN (2)

EFPADM3 Y0> → (3) 21YN (3)

Wattmetric based earth-faultprotection1)

WPWDE1 P0> → (1) 32N (1)

WPWDE2 P0> → (2) 32N (2)

WPWDE3 P0> → (3) 32N (3)

Transient / intermittent earth-faultprotection INTRPTEF1 I0> → IEF 67NIEF

Harmonics based earth-faultprotection1) HAEFPTOC1 I0>HA 51NHA

Non-directional (cross-country) earthfault protection, using calculated I0

EFHPTOC1 I0>> (1) 51N-2 (1)

Negative-sequence overcurrentprotection

NSPTOC1 I2> (1) 46 (1)

NSPTOC2 I2> (2) 46 (2)

Phase discontinuity protection PDNSPTOC1 I2/I1> 46PD

Residual overvoltage protection ROVPTOV1 U0> (1) 59G (1)

ROVPTOV2 U0> (2) 59G (2)

ROVPTOV3 U0> (3) 59G (3)

Three-phase undervoltage protection PHPTUV1 3U< (1) 27 (1)

PHPTUV2 3U< (2) 27 (2)

PHPTUV3 3U< (3) 27 (3)

Three-phase overvoltage protection PHPTOV1 3U> (1) 59 (1)

PHPTOV2 3U> (2) 59 (2)

PHPTOV3 3U> (3) 59 (3)

Positive-sequence undervoltageprotection

PSPTUV1 U1< (1) 47U+ (1)

PSPTUV2 U1< (2) 47U+ (2)

Negative-sequence overvoltageprotection

NSPTOV1 U2> (1) 47O- (1)

NSPTOV2 U2> (2) 47O- (2)

Frequency protection FRPFRQ1 f>/f<,df/dt (1) 81 (1)

FRPFRQ2 f>/f<,df/dt (2) 81 (2)





Three-phase thermal protection forfeeders, cables and distributiontransformers

T1PTTR1 3Ith>F 49F

Three-phase thermal overloadprotection for power transformers,two time constants

T2PTTR1 3Ith>T 49T




Function IEC 61850 IEC 60617 IEC-ANSINegative-sequence overcurrentprotection for motors

MNSPTOC1 I2>M (1) 46M (1)

MNSPTOC2 I2>M (2) 46M (2)

Loss of load supervision LOFLPTUC1 3I< 37

Motor load jam protection JAMPTOC1 Ist> 51LR

Motor start-up supervision STTPMSU1 Is2t n< 49,66,48,51LR

Phase reversal protection PREVPTOC1 I2>> 46R

Thermal overload protection formotors MPTTR1 3Ith>M 49M

Binary signal transfer BSTGGIO1 BST BST

Stabilized and instantaneousdifferential protection for 2W –transformers

TR2PTDF1 3dI>T 87T

Line differential protection andrelated measurements, stabilizedand instantaneous stages

LNPLDF1 3dI>L 87L

Numerical stabilized low impedancerestricted earth-fault protection LREFPNDF1 dI0L0> 87NL

High impedance based restrictedearth-fault protection HREFPDIF1 dI0Hi> 87NH

Circuit breaker failure protection CCBRBRF1 3I>/I0>BF 51BF/51NBF

Three-phase inrush detector INRPHAR1 3I2f> 68

Master trip TRPPTRC1 Master Trip (1) 94/86 (1)

TRPPTRC2 Master Trip (2) 94/86 (2)

Arc protection ARCSARC1 ARC (1) 50L/50NL (1)

ARCSARC2 ARC (2) 50L/50NL (2)

ARCSARC3 ARC (3) 50L/50NL (3)

Multi-purpose protection2) MAPGAPC1 MAP (1) MAP (1)

MAPGAPC2 MAP (2) MAP (2)





Load shedding and restoration LSHDPFRQ1 UFLS/R (1) 81LSH (1)

LSHDPFRQ2 UFLS/R (2) 81LSH (2)




Power quality

Current total demand distortion CMHAI1 PQM3I PQM3I

Voltage total harmonic distortion VMHAI1 PQM3U PQM3V

Voltage variation PHQVVR1 PQMU PQMV

Control




Function IEC 61850 IEC 60617 IEC-ANSICircuit-breaker control CBXCBR1 I ↔ O CB I ↔ O CB

Disconnector control DCXSWI1 I ↔ O DCC (1) I ↔ O DCC (1)

DCXSWI2 I ↔ O DCC (2) I ↔ O DCC (2)

Earthing switch control ESXSWI1 I ↔ O ESC I ↔ O ESC

Disconnector position indication DCSXSWI1 I ↔ O DC (1) I ↔ O DC (1)

DCSXSWI2 I ↔ O DC (2) I ↔ O DC (2)

DCSXSWI3 I ↔ O DC (3) I ↔ O DC (3)

Earthing switch indication ESSXSWI1 I ↔ O ES (1) I ↔ O ES (1)

ESSXSWI2 I ↔ O ES (2) I ↔ O ES (2)

Emergergency startup ESMGAPC1 ESTART ESTART

Auto-reclosing DARREC1 O → I 79

Tap changer position indication TPOSSLTC1 TPOSM 84M

Tap changer control with voltageregulator OLATCC1 COLTC 90V

Synchronism and energizing check SECRSYN1 SYNC 25

Condition monitoring

Circuit-breaker condition monitoring SSCBR1 CBCM CBCM

Trip circuit supervision TCSSCBR1 TCS (1) TCM (1)

TCSSCBR2 TCS (2) TCM (2)

Current circuit supervision CCRDIF1 MCS 3I MCS 3I

Fuse failure supervision SEQRFUF1 FUSEF 60

Protection communicationsupervision PCSRTPC1 PCS PCS

Runtime counter for machines anddevices MDSOPT1 OPTS OPTM

Measurement

Disturbance recorder RDRE1 - -

Three-phase current measurement CMMXU1 3I 3I

CMMXU2 3I(B) 3I(B)

Sequence current measurement CSMSQI1 I1, I2, I0 I1, I2, I0

Residual current measurement RESCMMXU1 I0 In

RESCMMXU2 I0(B) In(B)

Three-phase voltage measurement VMMXU1 3U 3U

Residual voltage measurement RESVMMXU1 U0 Vn

Sequence voltage measurement VSMSQI1 U1, U2, U0 U1, U2, U0

Three-phase power and energymeasurement PEMMXU1 P, E P, E

RTD/mA measurement XRGGIO130 X130 (RTD) X130 (RTD)

Frequency measurement FMMXU1 f f

1) One of the three following can be ordered as an option; Admittance based E/F, Wattmetric based E/F or Harmonics based E/F. The option is an addition to the existing E/F of the original configuration.The optional E/F has also a predefined configuration in the relay. The optional E/F can be set on or



off. NOTICE! The existing E/F of the configuration, (DEFx), is always present in the configurationeven if it is an option in the order code sheet.

2) Multi-purpose protection is used, for example, for RTD/mA based protection.



Section 2 615 series overview

2.1 Overview

615 series is a product family of IEDs designed for protection, control,measurement and supervision of utility substations and industrial switchgear andequipment. The design of the IEDs has been guided by the IEC 61850 standard forcommunication and interoperability of substation automation devices.

The IEDs feature draw-out-type design with a variety of mounting methods,compact size and ease of use. Depending on the product, optional functionality isavailable at the time of order for both software and hardware, for example,autoreclosure and additional I/Os.

The 615 series IEDs support a range of communication protocols including IEC61850 with GOOSE messaging, IEC 60870-5-103, Modbus® and DNP3.

1MRS756887 G Section 2615 series overview


2.1.1 Product series version historyProduct series version Product series history1.0 First product from 615 series REF615 released with configurations A-D

1.1 New product: RED615 Platform enhancements:

• IRIG-B support• Support for parallel protocols: IEC 61850 and Modbus• Additional binary input/output module X130 as an option• Enhanced CB interlocking functionality• Enhanced TCS functionality in HW• Non-volatile memory support

2.0 New products:

• RET615 with configurations A-D• REM615 with configuration C

New configurations

• REF615: E and F• RED615: B and C

Platform enhancements

• Support for DNP3 serial or TCP/IP• Support for IEC 60870-5-103• Voltage measurement and protection• Power and energy measurement• Disturbance recorder upload via WHMI• Fuse failure supervision

Section 2 1MRS756887 G615 series overview


Product series version Product series history3.0 New product:

• REU615 with configurations A and B

New configurations:

• REF615 G and H• RET615 E-H• REM615 A and B

Additions for configurations:

• REF615 A, B, E and F• RET615 A-D• REM615 C• RED615 B

Platform enhancements:

• Application configurability support• Analog GOOSE support• Large display with single line diagram• Enhanced mechanical design• Increased maximum amount of events and fault records• Frequency measurement and protection• Admittance-based earth fault• Combi sensor inputs• RTD/mA measurement and protection• Synchronism and energizing check• Tap changer control with voltage regulator• Load shedding and restoration• Measured/calculated Io/Uo selectable• Multi-port Ethernet option

4.0 New configuration:

• REF615 J

Additions/changes for configurations:

• REF615 A-H• RET615 A-H• REM615 A-C• RED615 A-C• REU615 A-B

Platform enhancements:

• Dual fibre optic Ethernet communication option (COM0032)• Generic control point (SPCGGIO) function blocks• Additional logic blocks• Button object for SLD• Controllable disconnector and earth switch objects for SLD• Wattmetric based E/F• Harmonics based E/F• Power Quality functions• Additional multi-purpose protection instances• Increased maximum amount of events and fault records




Product series version Product series history4.0 FP1 Platform enhancements:

• High-availability seamless redundancy (HSR)• Parallel redundancy protocol (PRP-1)• Support for parallel protocols:

• IEC 61850 and IEC 60870-5-103• IEC 61850 and DNP3

• Programmable LEDs• Online monitoring for PCM600

2.1.2 PCM600 and IED connectivity package version• Protection and Control IED Manager PCM600 Ver. 2.5 or later• RED615 Connectivity Package Ver. 4.1 or later• REF615 Connectivity Package Ver. 4.1 or later• REM615 Connectivity Package Ver. 4.1 or later• RET615 Connectivity Package Ver. 4.1 or later• REU615 Connectivity Package Ver. 4.1 or later

Download connectivity packages from the ABB Websitehttp://www.abb.com/substationautomation.

2.2 Local HMI

The LHMI is used for setting, monitoring and controlling the IED. The LHMIcomprises the display, buttons, LED indicators and communication port.




REF615

Overcurrent

Dir. earth-fault

Voltage protection

Phase unbalance

Thermal overload

Breaker failure

Disturb. rec. Triggered

CB condition monitoring

Supervision

Arc detected

Autoreclose shot in progr.

A070704 V3 EN

Figure 1: Example of the LHMI

2.2.1 DisplayThe LHMI includes a graphical display that supports two character sizes. Thecharacter size depends on the selected language. The amount of characters androws fitting the view depends on the character size.

Table 2: Small display

Character size1) Rows in the view Characters per rowSmall, mono-spaced (6x12 pixels) 5 20

Large, variable width (13x14 pixels) 4 8 or more

1) Depending on the selected language

Table 3: Large display

Character size1) Rows in the view Characters per rowSmall, mono-spaced (6x12 pixels) 10 20

Large, variable width (13x14 pixels) 8 8 or more

1) Depending on the selected language



The display view is divided into four basic areas.

1 2

3 4A070705 V3 EN

Figure 2: Display layout

1 Header

2 Icon

3 Content

4 Scroll bar (displayed when needed)

2.2.2 LEDsThe LHMI includes three protection indicators above the display: Ready, Start andTrip.

There are also 11 matrix programmable LEDs on front of the LHMI. The LEDscan be configured with PCM600 and the operation mode can be selected with theLHMI, WHMI or PCM600.

2.2.3 KeypadThe LHMI keypad contains push-buttons which are used to navigate in differentviews or menus. With the push-buttons you can give open or close commands toobjects in the primary circuit, for example, a circuit breaker, a contactor or adisconnector. The push-buttons are also used to acknowledge alarms, resetindications, provide help and switch between local and remote control mode.



A071176 V1 EN

Figure 3: LHMI keypad with object control, navigation and command push-buttons and RJ-45 communication port

2.3 Web HMI

The WHMI allows accessing the IED via a Web browser. The supported Webbrowser versions are Internet Explorer 7.0, 8.0 and 9.0.

WHMI is disabled by default.

WHMI offers several functions.

• Programmable LEDs and event lists• System supervision• Parameter settings• Measurement display• Disturbance records• Phasor diagram• Single-line diagram

The menu tree structure on the WHMI is almost identical to the one on the LHMI.



A070754 V4 EN

Figure 4: Example view of the WHMI

The WHMI can be accessed locally and remotely.

• Locally by connecting the laptop to the IED via the front communication port.• Remotely over LAN/WAN.

2.4 Authorization

The user categories have been predefined for the LHMI and the WHMI, each withdifferent rights and default passwords.

The default passwords can be changed with Administrator user rights.

User authorization is disabled by default for LHMI but WHMIalways uses authorization.



Table 4: Predefined user categories

Username User rightsVIEWER Read only access

OPERATOR • Selecting remote or local state with (only locally)• Changing setting groups• Controlling• Clearing indications

ENGINEER • Changing settings• Clearing event list• Clearing disturbance records• Changing system settings such as IP address, serial baud rate

or disturbance recorder settings• Setting the IED to test mode• Selecting language

ADMINISTRATOR • All listed above• Changing password• Factory default activation

For user authorization for PCM600, see PCM600 documentation.

2.4.1 Audit trailThe IED offers a large set of event-logging functions. Normal process-relatedevents can be viewed by the normal user with Event Viewer in PCM600. Criticalsystem and IED security-related events are logged to a separate nonvolatile audittrail for the administrator.

Audit trail is a chronological record of system activities that allows thereconstruction and examination of the sequence of events and changes in an event.Past user and process events can be examined and analyzed in a consistent methodwith the help of Event List and Event Viewer in PCM600. The IED stores 2048system events to the nonvolatile audit trail. Additionally, 1024 process events arestored in a nonvolatile event list. Both the audit trail and event list work accordingto the FIFO principle.

User audit trail is defined according to the selected set of requirements from IEEE1686. The logging is based on predefined usernames or user categories. The useraudit trail events are supported in IEC 61850-8-1, PCM600, LHMI and WHMI.

Table 5: Audit trail events

Audit trail event DescriptionConfiguration change Configuration files changed

Firmware change

Setting group remote User changed setting group remotely




Audit trail event DescriptionSetting group local User changed setting group locally

Control remote DPC object control remote

Control local DPC object control local

Test on Test mode on

Test off Test mode off

Setting commit Settings have been changed

Time change

View audit log Administrator accessed audit trail

Login

Logout

Firmware reset Reset issued by user or tool

Audit overflow Too many audit events in the time period

PCM600 Event Viewer can be used to view the audit trail events together withnormal events. Since only the administrator has the right to read audit trail,authorization must be properly configured in PCM600. The audit trail cannot bereset but PCM600 Event Viewer can filter data. Some of the audit trail events areinteresting also as normal process events.

To expose the audit trail events also as normal process events,define the level parameter via Configuration/Authorization/Authority logging.

Table 6: Comparison of authority logging levels

Audit trail event Authority logging level

NoneConfiguration change

Settinggroup

Settinggroup,control

Settingsedit

All

Configuration change

Firmware change

Setting group remote

Setting group local

Control remote

Control local

Test on

Test off

Setting commit

Time change

View audit log

Login




Audit trail event Authority logging levelLogout

Firmware reset

Audit overflow

2.5 Communication

The IED supports a range of communication protocols including IEC 61850, IEC60870-5-103, Modbus® and DNP3. Operational information and controls areavailable through these protocols. However, some communication functionality,for example, horizontal communication between the IEDs, is only enabled by theIEC 61850 communication protocol.

The IEC 61850 communication implementation supports all monitoring andcontrol functions. Additionally, parameter settings, disturbance recordings andfault records can be accessed using the IEC 61850 protocol. Disturbance recordingsare available to any Ethernet-based application in the standard COMTRADE fileformat. The IED can send and receive binary signals from other IEDs (so-calledhorizontal communication) using the IEC61850-8-1 GOOSE profile, where thehighest performance class with a total transmission time of 3 ms is supported.Furthermore, the IED supports sending and receiving of analog values usingGOOSE messaging. The IED meets the GOOSE performance requirements fortripping applications in distribution substations, as defined by the IEC 61850standard. The IED can simultaneously report events to five different clients on thestation bus.

The IED can support five simultaneous clients. If PCM600 reserves one clientconnection, only four client connections are left, for example, for IEC 61850 andModbus.

All communication connectors, except for the front port connector, are placed onintegrated optional communication modules. The IED can be connected to Ethernet-based communication systems via the RJ-45 connector (100Base-TX) or the fibre-optic LC connector (100Base-FX).

For the correct operation of redundant loop topology, it is essential that the externalswitches in the network support the RSTP protocol and that it is enabled in theswitches. Otherwise, connecting the loop topology can cause problems to thenetwork. The IED itself does not support link-down detection or RSTP. The ringrecovery process is based on the aging of the MAC addresses, and the link-up/link-down events can cause temporary breaks in communication. For a betterperformance of the self-healing loop, it is recommended that the external switchfurthest from the IED loop is assigned as the root switch (bridge priority = 0) andthe bridge priority increases towards the IED loop. The end links of the IED loopcan be attached to the same external switch or to two adjacent external switches. Aself-healing Ethernet ring requires a communication module with at least twoEthernet interfaces for all IEDs.



Managed Ethernet switchwith RSTP support

Managed Ethernet switchwith RSTP support

Client BClient A

Network ANetwork B

GUID-283597AF-9F38-4FC7-B87A-73BFDA272D0F V3 EN

Figure 5: Self-healing Ethernet ring solution

The Ethernet ring solution supports the connection of up to 30IEDs. If more than 30 IEDs are to be connected, it is recommendedthat the network is split into several rings with no more than 30IEDs per ring. Each IED has a 50-μs store-and-forward delay, andto fullfill the performance requirements for fast horizontalcommunication, the ring size is limited to 30 IEDs.

2.5.1 Ethernet redundancyIEC 61850 specifies a network redundancy scheme that improves the systemavailability for substation communication. It is based on two complementaryprotocols defined in the IEC 62439-3 standard: parallel redundancy protocol PRPand high-availability seamless redundancy HSR protocol. Both the protocols relyon the duplication of all transmitted information via two Ethernet ports for onelogical network connection. Therefore, both are able to overcome the failure of alink or switch with a zero-switchover time, thus fulfilling the stringent real-timerequirements for the substation automation horizontal communication and timesynchronization.

PRP specifies that each device is connected in parallel to two local area networks.HSR applies the PRP principle to rings and to the rings of rings to achieve cost-effective redundancy. Thus, each device incorporates a switch element thatforwards frames from port to port. The HSR/PRP option is available for REF615,REM615, RET615 and REU615.



PRPEach PRP node, called a doubly attached node with PRP (DANP), is attached totwo independent LANs operated in parallel. These parallel networks in PRP arecalled LAN A and LAN B. The networks are completely separated to ensure failureindependence, and they can have different topologies. Both networks operate inparallel, thus providing zero-time recovery and continuous checking of redundancyto avoid communication failures. Non-PRP nodes, called singly attached nodes(SANs), are either attached to one network only (and can therefore communicateonly with DANPs and SANs attached to the same network), or are attached througha redundancy box, a device that behaves like a DANP.

Ethernet switchIEC 61850 PRPEthernet switch

REF615 REF620 RET620 REM620 REF615

SCADACOM600

GUID-334D26B1-C3BD-47B6-BD9D-2301190A5E9D V1 EN

Figure 6: PRP solution

In case a laptop or a PC workstation is connected as a non-PRP node to one of thePRP networks, LAN A or LAN B, it is recommended to use a redundancy boxdevice or an Ethernet switch with similar functionality between the PRP networkand SAN to remove additional PRP information from the Ethernet frames. In somecases, default PC workstation adapters are not able to handle the maximum-lengthEthernet frames with the PRP trailer.

There are three alternative ways to connect a laptop or a workstation as SAN to thePRP network.

• Via an external redundancy box or a switch capable of connecting to PRP andnormal networks

• By connecting the node directly to the IED interlink port (IED operates as aredundancy box)

• By using an Ethernet adapter compatible with the PRP frame, and connectingdirectly to one of the PRP networks



HSRHSR applies the PRP principle of parallel operation to a single ring, treating thetwo directions as two virtual LANs. For each frame sent, a node, DANH, sends twoframes, one over each port. Both frames circulate in opposite directions over thering and each node forwards the frames it receives, from one port to the other.When the originating node receives a frame sent to itself, it discards that to avoidloops; therefore, no ring protocol is needed. Individually attached nodes, SANs,such as laptops and printers, must be attached through a “redundancy box” that actsas a ring element. For example, a 615 series IED with HSR support can be used asa redundancy box.

GUID-207430A7-3AEC-42B2-BC4D-3083B3225990 V1 EN

Figure 7: HSR solution



Section 3 Basic functions

3.1 General parameters

Table 7: Analog input settings, phase currents

Parameter Values (Range) Unit Step Default DescriptionSecondary current 2=1A

3=5A 2=1A Rated secondary current

Primary current 1.0...6000.0 A 0.1 100.0 Rated primary current

Amplitude corr. A 0.900...1.100 0.001 1.000 Phase A amplitude correction factor

Amplitude corr. B 0.900...1.100 0.001 1.000 Phase B amplitude correction factor

Amplitude corr. C 0.900...1.100 0.001 1.000 Phase C amplitude correction factor

Nominal Current 39...4000 A 1 1300 Network Nominal Current (In)

Rated Secondary Value 1.000...50.000 mV/Hz 0.001 3.000 Rated Secondary Value (RSV) ratio

Reverse polarity 0=False1=True

0=False Reverse the polarity of the phase CTs

Table 8: Analog input settings, residual current

Parameter Values (Range) Unit Step Default DescriptionSecondary current 1=0.2A

2=1A3=5A

2=1A Secondary current

Primary current 1.0...6000.0 A 0.1 100.0 Primary current

Amplitude corr. 0.900...1.100 0.001 1.000 Amplitude correction

Reverse polarity 0=False1=True

0=False Reverse the polarity of the residual CT

Table 9: Analog input settings, phase voltages

Parameter Values (Range) Unit Step Default DescriptionPrimary voltage 0.100...440.000 kV 0.001 20.000 Primary rated voltage

Secondary voltage 60...210 V 1 100 Secondary rated voltage

VT connection 1=Wye2=Delta3=U124=UL1

2=Delta Wye, delta, U12 or UL1 VT connection

Amplitude corr. A 0.900...1.100 0.001 1.000 Phase A Voltage phasor magnitudecorrection of an external voltagetransformer


1MRS756887 G Section 3Basic functions


Parameter Values (Range) Unit Step Default DescriptionAmplitude corr. B 0.900...1.100 0.001 1.000 Phase B Voltage phasor magnitude

correction of an external voltagetransformer

Amplitude corr. C 0.900...1.100 0.001 1.000 Phase C Voltage phasor magnitudecorrection of an external voltagetransformer

Division ratio 1000...20000 1 10000 Voltage sensor division ratio

Voltage input type 1=Voltage trafo3=CVD sensor

1=Voltage trafo Type of the voltage input

Table 10: Analog input settings, residual voltage

Parameter Values (Range) Unit Step Default DescriptionSecondary voltage 60...210 V 1 100 Secondary voltage

Primary voltage 0.100...440.000 kV 0.001 11.547 Primary voltage

Amplitude corr. 0.900...1.100 0.001 1.000 Amplitude correction

Table 11: Authorization settings

Parameter Values (Range) Unit Step Default DescriptionLocal override 0=False 1)

1=True 2) 1=True Disable authority

Remote override 0=False 3)

1=True 4) 1=True Disable authority

Local viewer 0 Set password

Local operator 0 Set password

Local engineer 0 Set password

Local administrator 0 Set password

Remote viewer 0 Set password

Remote operator 0 Set password

Remote engineer 0 Set password

Remote administrator 0 Set password

1) Authorization override is disabled, LHMI password must be entered.2) Authorization override is enabled, LHMI password is not asked.3) Authorization override is disabled, communication tools ask password to enter the IED.4) Authorization override is enabled, communication tools do not need password to enter the IED, except for WHMI which always requires it.

Table 12: Binary input settings

Parameter Values (Range) Unit Step Default DescriptionThreshold voltage 18...176 Vdc 2 18 Binary input threshold voltage

Input osc. level 2...50 events/s 1 30 Binary input oscillation suppressionthreshold

Input osc. hyst 2...50 events/s 1 10 Binary input oscillation suppressionhysteresis

Section 3 1MRS756887 GBasic functions


Table 13: Ethernet front port settings

Parameter Values (Range) Unit Step Default DescriptionIP address 192.168.0.254 IP address for front port (fixed)

Mac address XX-XX-XX-XX-XX-XX

Mac address for front port

Table 14: Ethernet rear port settings

Parameter Values (Range) Unit Step Default DescriptionIP address 192.168.2.10 IP address for rear port(s)

Subnet mask 255.255.255.0 Subnet mask for rear port(s)

Default gateway 192.168.2.1 Default gateway for rear port(s)

Mac address XX-XX-XX-XX-XX-XX

Mac address for rear port(s)

Table 15: Redundancy settings

Parameter Values (Range) Unit Step Default DescriptionSwitch mode Normal

HSRPRP

Normal Mode selection for Ethernet switch onRedundant communication modules

Table 16: DIAGLCCH1 Output signals

Name Values DescriptionCHLIV True

FalseStatus of LAN A in HSR mode

REDCHLIV TrueFalse

Status of LAN B in HSR mode

Table 17: XGGIO90 Output signals

Name Values DescriptionETHLNK1 Up

DownStatus of Ethernet link 1

ETHLNK2 UpDown

Status of Ethernet link 2

ETHLNK3 UpDown

Status of Ethernet link 3



Table 18: General system settings

Parameter Values (Range) Unit Step Default DescriptionRated frequency 1=50Hz

2=60Hz 1=50Hz Rated frequency of the network

Phase rotation 1=ABC2=ACB

1=ABC Phase rotation order

Blocking mode 1=Freeze timer2=Block all3=Block OPERATEoutput

1=Freeze timer Behaviour for function BLOCK inputs

Bay name1) REF6152) Bay name in system

IDMT Sat point 10...50 I/I> 1 50 Overcurrent IDMT saturation point

1) Used in the IED main menu header and as part of the disturbance recording identification2) Depending on the product variant

Table 19: HMI settings

Parameter Values (Range) Unit Step Default DescriptionFB naming convention 1=IEC61850

2=IEC606173=IEC-ANSI

1=IEC61850 FB naming convention used in IED

Default view 1=Measurements2=Main menu3=SLD

1=Measurements LHMI default view

Backlight timeout 1...60 min 1 3 LHMI backlight timeout

Web HMI mode 1=Active read only2=Active3=Disabled

3=Disabled Web HMI functionality

Web HMI timeout 1...60 min 1 3 Web HMI login timeout

SLD symbol format 1=IEC2=ANSI

1=IEC Single Line Diagram symbol format

Autoscroll delay 0...30 s 1 0 Autoscroll delay for Measurements view

Table 20: IEC 60870-5-103 settings

Parameter Values (Range) Unit Step Default DescriptionSerial port 1 0=Not in use

1=COM 12=COM 2

0=Not in use COM port for instance 1

Address 1 1...255 1 Unit address for instance 1

Start delay 1 0...20 char 4 Start frame delay in chars for instance 1

End delay 1 0...20 char 4 End frame delay in chars for instance 1

DevFunType 1 0...255 9 Device Function Type for instance 1

UsrFType 1 0...255 10 Function type for User Class 2 Frame forinstance 1

UsrInfNo 1 0...255 230 Information Number for User Class2Frame for instance 1




Parameter Values (Range) Unit Step Default DescriptionClass1Priority 1 0=Ev High

1=Ev/DR Equal2=DR High

0=Ev High Class 1 data sending priority relationshipbetween Events and DisturbanceRecorder data.

Frame1InUse 1 -1=Not in use0=User frame1=Standard frame12=Standard frame23=Standard frame34=Standard frame45=Standard frame56=Private frame 67=Private frame 7

6=Private frame 6 Active Class2 Frame 1 for instance 1


-1=Not in use Active Class2 Frame 2 for instance 1








Parameter Values (Range) Unit Step Default DescriptionClass1OvInd 1 0=No indication

1=Both edges2=Rising edge

2=Rising edge Overflow Indication for instance 1

Class1OvFType 1 0...255 10 Function Type for Class 1 overflowindication for instance 1

Class1OvInfNo 1 0...255 255 Information Number for Class 1 overflowindication for instance 1

Class1OvBackOff 1 0...500 500 Backoff Range for Class1 buffer forinstance 1

GI Optimize 1 0=Standardbehaviour1=Skipspontaneous2=Only overflown3=Combined

0=Standardbehaviour

Optimize GI traffic for instance 1

DR Notification 1 0=Disabled1=Enabled

0=Disabled Disturbance Recorder spontaneousindications enabled/disabled

Serial port 2 0=Not in use1=COM 12=COM 2

0=Not in use COM port for instance 2

Address 2 1...255 1 Unit address for instance 2

Start delay 2 0...20 char 4 Start frame delay in chars for instance 2

End delay 2 0...20 char 4 End frame delay in chars for instance 2

DevFunType 2 0...255 9 Device Function Type for instance 2

UsrFType 2 0...255 10 Function type for User Class 2 Frame forinstance 2

UsrInfNo 2 0...255 230 Information Number for User Class2Frame for instance 2

Class1Priority 2 0=Ev High1=Ev/DR Equal2=DR High

0=Ev High Class 1 data sending priority relationshipbetween Events and DisturbanceRecorder data.


6=Private frame 6 Active Class2 Frame 1 for instance 2




Parameter Values (Range) Unit Step Default DescriptionFrame2InUse 2 -1=Not in use

0=User frame1=Standard frame12=Standard frame23=Standard frame34=Standard frame45=Standard frame56=Private frame 67=Private frame 7






Class1OvInd 2 0=No indication1=Both edges2=Rising edge

2=Rising edge Overflow Indication for instance 2

Class1OvFType 2 0...255 10 Function Type for Class 1 overflowindication for instance 2

Class1OvInfNo 2 0...255 255 Information Number for Class 1 overflowindication for instance 2

Class1OvBackOff 2 0...500 500 Backoff Range for Class1 buffer forinstance 2

GI Optimize 2 0=Standardbehaviour1=Skipspontaneous2=Only overflown3=Combined

0=Standardbehaviour

Optimize GI traffic for instance 2

DR Notification 2 0=Disabled1=Enabled

0=Disabled Disturbance Recorder spontaneousindications enabled/disabled



Table 21: IEC 61850-8-1 MMS settings

Parameter Values (Range) Unit Step Default DescriptionUnit mode 1=Primary

0=Nominal2=Primary-Nominal

0=Nominal IEC 61850-8-1 unit mode

Table 22: Modbus settings

Parameter Values (Range) Unit Step Default DescriptionSerial port 1 0=Not in use

1=COM 12=COM 2

0=Not in use COM port for Serial interface 1

Parity 1 0=none1=odd2=even

2=even Parity for Serial interface 1

Address 1 1...255 1 Modbus unit address on Serial interface 1

Link mode 1 1=RTU2=ASCII

1=RTU Modbus link mode on Serial interface 1

Start delay 1 0...20 char 4 Start frame delay in chars on Serialinterface 1

End delay 1 0...20 char 3 End frame delay in chars on Serialinterface 1

Serial port 2 0=Not in use1=COM 12=COM 2

0=Not in use COM port for Serial interface 2

Parity 2 0=none1=odd2=even

2=even Parity for Serial interface 2

Address 2 1...255 2 Modbus unit address on Serial interface 2

Link mode 2 1=RTU2=ASCII

1=RTU Modbus link mode on Serial interface 2

Start delay 2 0...20 4 Start frame delay in chars on Serialinterface 2

End delay 2 0...20 3 End frame delay in chars on Serialinterface 2

MaxTCPClients 0...5 5 Maximum number of Modbus TCP/IPclients

TCPWriteAuthority 0=No clients1=Reg. clients2=All clients

2=All clients Write authority setting for Modbus TCP/IP clients

EventID 0=Address1=UID

0=Address Event ID selection

TimeFormat 0=UTC1=Local

1=Local Time format for Modbus time stamps

ClientIP1 000.000.000.000 Modbus Registered Client 1








Parameter Values (Range) Unit Step Default DescriptionCtlStructPWd1 **** Password for Modbus control struct 1

CtlStructPWd2 **** Password for Modbus control struct 2







Table 23: DNP3 settings

Parameter Values (Range) Unit Step Default DescriptionDNP physical layer 1=Serial

2=TCP/IP 2=TCP/IP DNP physical layer

Unit address 1...65519 1 1 DNP unit address

Master address 1...65519 1 3 DNP master and UR address

Serial port 0=Not in use1=COM 12=COM 2

0=Not in use COM port for serial interface, whenphysical layer is serial.

Need time interval 0...65535 min 1 30 Period to set IIN need time bit

Time format 0=UTC1=Local

1=Local UTC or local. Coordinate with master.

CROB select timeout 1...65535 sec 1 10 Control Relay Output Block select timeout

Data link confirm 0=Never1=Only Multiframe2=Always

0=Never Data link confirm mode

Data link confirm TO 100...65535 ms 1 3000 Data link confirm timeout

Data link retries 0...65535 1 3 Data link retries count

Data link Rx to Tx delay 0...255 ms 1 0 Turnaround transmission delay

Data link inter char delay 0...20 char 1 4 Inter character delay for incomingmessages

App layer confirm 1=Disable2=Enable

1=Disable Application layer confirm mode

App confirm TO 100...65535 ms 1 5000 Application layer confirm and UR timeout

App layer fragment 256...2048 bytes 1 2048 Application layer fragment size

UR mode 1=Disable2=Enable

1=Disable Unsolicited responses mode

UR retries 0...65535 1 3 Unsolicited retries before switching toUR offline mode

UR TO 0...65535 ms 1 5000 Unsolicited response timeout

UR offline interval 0...65535 min 1 15 Unsolicited offline interval

UR Class 1 Min events 0...999 1 2 Min number of class 1 events togenerate UR

UR Class 1 TO 0...65535 ms 1 50 Max holding time for class 1 events togenerate UR




Parameter Values (Range) Unit Step Default DescriptionUR Class 2 Min events 0...999 1 2 Min number of class 2 events to

generate UR


UR Class 3 Min events 0...999 1 2 Min number of class 3 events togenerate UR


Legacy master UR 1=Disable2=Enable

1=Disable Legacy DNP master unsolicited modesupport. When enabled relay does notsend initial unsolicited message.

Legacy master SBO 1=Disable2=Enable

1=Disable Legacy DNP Master SBO sequencenumber relax enable

Default Var Obj 01 1...2 1 1 1=BI; 2=BI with status.

Default Var Obj 02 1...2 1 2 1=BI event; 2=BI event with time.

Default Var Obj 30 1...4 1 2 1=32 bit AI; 2=16 bit AI; 3=32 bit AIwithout flag; 4=16 bit AI without flag.

Default Var Obj 32 1...4 1 4 1=32 bit AI event; 2=16 bit AI event;3=32 bit AI event with time; 4=16 bit AIevent with time.

Table 24: Serial communication settings

Parameter Values (Range) Unit Step Default DescriptionFiber mode 0=No fiber

2=Fiber optic 0=No fiber Fiber mode for COM1

Serial mode 1=RS485 2Wire2=RS485 4Wire3=RS232 nohandshake4=RS232 withhandshake

1=RS485 2Wire Serial mode for COM1

CTS delay 0...60000 0 CTS delay for COM1

RTS delay 0...60000 0 RTS delay for COM1

Baudrate 1=3002=6003=12004=24005=48006=96007=192008=384009=5760010=115200

6=9600 Baudrate for COM1



Table 25: Serial communication settings

Parameter Values (Range) Unit Step Default DescriptionFiber mode 0=No fiber

2=Fiber optic 0=No fiber Fiber mode for COM2

Serial mode 1=RS485 2Wire2=RS485 4Wire3=RS232 nohandshake4=RS232 withhandshake

1=RS485 2Wire Serial mode for COM2

CTS delay 0...60000 0 CTS delay for COM2

RTS delay 0...60000 0 RTS delay for COM2

Baudrate 1=3002=6003=12004=24005=48006=96007=192008=384009=5760010=115200

6=9600 Baudrate for COM2

Table 26: Time settings

Parameter Values (Range) Unit Step Default DescriptionDate 0 Date

Time 0 Time

Time format 1=24H:MM:SS:MS2=12H:MM:SS:MS

1=24H:MM:SS:MS

Time format

Date format 1=DD.MM.YYYY2=DD/MM/YYYY3=DD-MM-YYYY4=MM.DD.YYYY5=MM/DD/YYYY6=YYYY-MM-DD7=YYYY-DD-MM8=YYYY/DD/MM

1=DD.MM.YYYY Date format

Local time offset -720...720 min 0 Local time offset in minutes

Synch source 0=None1=SNTP2=Modbus5=IRIG-B8=Line differential9=DNP17=IEC60870-5-103

1=SNTP Time synchronization source

IP SNTP primary 10.58.125.165 IP address for SNTP primary server

IP SNTP secondary 192.168.2.165 IP address for SNTP secondary server

DST on time 02:00 Daylight savings time on, time (hh:mm)

DST on date 01.05 Daylight savings time on, date (dd.mm)




Parameter Values (Range) Unit Step Default DescriptionDST on day 0=Not in use

1=Mon2=Tue3=Wed4=Thu5=Fri6=Sat7=Sun

0=Not in use Daylight savings time on, day of week

DST offset -720...720 min 60 Daylight savings time offset, in minutes

DST off time 02:00 Daylight savings time off, time (hh:mm)

DST off date 25.09 Daylight savings time off, date (dd.mm)

DST off day 0=Not in use1=Mon2=Tue3=Wed4=Thu5=Fri6=Sat7=Sun

0=Not in use Daylight savings time off, day of week

Table 27: X100 PSM binary output signals

Name Type Default DescriptionX100-PO1 BOOLEAN 0=False Connectors 6-7

X100-PO2 BOOLEAN 0=False Connectors 8-9

X100-SO1 BOOLEAN 0=False Connectors10c-11nc-12no

X100-SO2 BOOLEAN 0=False Connectors 13c-14no

X100-PO3 BOOLEAN 0=False Connectors15-17/18-19

X100-PO4 BOOLEAN 0=False Connectors20-22/23-24

Table 28: X110 BIO binary output signals

Name Type Default DescriptionX110-SO1 BOOLEAN 0=False Connectors

14c-15no-16nc

X110-SO2 BOOLEAN 0=False Connectors17c-18no-19nc


X110-SO4 BOOLEAN 0=False Connectors 23-24



Table 29: X110 BIO binary input signals

Name Type DescriptionX110-Input 1 BOOLEAN Connectors 1-2

X110-Input 2 BOOLEAN Connectors 3-4

X110-Input 3 BOOLEAN Connectors 5-6c






Table 30: X110 BIO binary input settings

Parameter Values (Range) Unit Step Default DescriptionInput 1 filter time 5...1000 ms 5 Connectors 1-2

Input 2 filter time 5...1000 ms 5 Connectors 3-4

Input 3 filter time 5...1000 ms 5 Connectors 5-6c






Input 1 inversion 0=False1=True

0=False Connectors 1-2




0=False Connectors 5-6c













Table 31: X120 AIM binary input signals

Name Type DescriptionX120-Input 1 BOOLEAN Connectors 1-2c




Table 32: X120 AIM binary input settings

Parameter Values (Range) Unit Step Default DescriptionInput 1 filter time 5...1000 ms 5 Connectors 1-2c












Table 33: X130 BIO binary output signals

Name Type Default DescriptionX130-SO1 BOOLEAN 0=False Connectors

10c-11no-12nc



Table 34: X130 BIO binary input signals

Name Type DescriptionX130-Input 1 BOOLEAN Connectors 1-2c








Table 35: X130 BIO binary input settings

Parameter Values (Range) Unit Step Default DescriptionInput 1 filter time 5...1000 ms 5 Connectors 1-2c


















Table 36: X130 AIM binary input signals

Name Type DescriptionX130-Input 1 BOOLEAN Connectors 1-2




Table 37: X130 AIM binary input settings

Parameter Values (Range) Unit Step Default DescriptionInput 1 filter time 5...1000 ms 5 Connectors 1-2














3.2 Self-supervision

The IED's extensive self-supervision system continuously supervises the softwareand the electronics. It handles run-time fault situation and informs the user about afault via the LHMI and through the communications channels.

There are two types of fault indications.

• Internal faults• Warnings

3.2.1 Internal faultsWhen an IED internal fault is detected, IED protection operation is disabled, thegreen Ready LED begins to flash and the self-supervision output contact is activated.

Internal fault indications have the highest priority on the LHMI.None of the other LHMI indications can override the internal faultindication.

An indication about the fault is shown as a message on the LHMI. The textInternal Fault with an additional text message, a code, date and time, isshown to indicate the fault type.

Different actions are taken depending on the severity of the fault. The IED tries toeliminate the fault by restarting. After the fault is found to be permanent, the IEDstays in the internal fault mode. All other output contacts are released and lockedfor the internal fault. The IED continues to perform internal tests during the faultsituation.

If an internal fault disappears, the green Ready LED stops flashing and the IEDreturns to the normal service state. The fault indication message remains on thedisplay until manually cleared.

The self-supervision signal output operates on the closed-circuit principle. Undernormal conditions, the IED is energized and the contact gaps 3-5 in slot X100 isclosed. If the auxiliary power supply fails or an internal fault is detected, thecontact gaps 3-5 are opened.



A070789 V1 EN

Figure 8: Output contact

The internal fault code indicates the type of internal IED fault. When a faultappears, the code must be recorded so that it can be reported to ABB customer service.

Table 38: Internal fault indications and codes

Fault indication Fault code Additional informationInternal FaultSystem error

2 An internal system error has occurred.

Internal FaultFile system error

7 A file system error has occurred.

Internal FaultTest

8 Internal fault test activated manually bythe user.

Internal FaultSW watchdog error

10 Watchdog reset has occurred too manytimes within an hour.

Internal FaultSO-relay(s),X100

43 Faulty Signal Output relay(s) in cardlocated in slot X100.







Internal FaultPO-relay(s),X100

53 Faulty Power Output relay(s) in cardlocated in slot X100.







Internal FaultLight sensor error

57 Faulty ARC light sensor input(s).

Internal FaultConf. error,X000

62 Card in slot X000 is wrong type.


63 Card in slot X100 is wrong type or doesnot belong to the original composition.




Fault indication Fault code Additional informationInternal FaultConf. error,X110

64 Card in slot X110 is wrong type, ismissing or does not belong to the originalcomposition.



Internal FaultConf.error,X130


Internal FaultCard error,X000

72 Card in slot X000 is faulty.









Internal FaultLHMI module

79 LHMI module is faulty. The faultindication may not be seen on the LHMIduring the fault.

Internal FaultRAM error

80 Error in the RAM memory on the CPUcard.

Internal FaultROM error

81 Error in the ROM memory on the CPUcard.

Internal FaultEEPROM error

82 Error in the EEPROM memory on theCPU card.

Internal FaultFPGA error

83 Error in the FPGA on the CPU card.

Internal FaultRTC error

84 Error in the RTC on the CPU card.

Internal FaultRTD card error,X130

96 RTD card located in slot X130 may havepermanent fault. Temporary error hasoccurred too many times within a shorttime.

For further information on internal fault indications, see the operation manual.

3.2.2 WarningsIn case of a warning, the IED continues to operate except for those protectionfunctions possibly affected by the fault, and the green Ready LED remains lit asduring normal operation.

Warnings are indicated with the text Warning additionally provided with thename of the warning, a numeric code and the date and time on the LHMI. Thewarning indication message can be manually cleared.



If a warning appears, record the name and code so that it can beprovided to ABB customer service.

Table 39: Warning indications and codes

Warning indication Warning code Additional informationWarningWatchdog reset

10 A watchdog reset has occurred.

WarningPower down det.

11 The auxiliary supply voltage has droppedtoo low.

WarningIEC61850 error

20 Error when building the IEC 61850 datamodel.

WarningModbus error

21 Error in the Modbus communication.

WarningDNP3 error

22 Error in the DNP3 communication.

WarningDataset error

24 Error in the Data set(s).

WarningReport cont. error

25 Error in the Report control block(s).

WarningGOOSE contr. error

26 Error in the GOOSE control block(s).

WarningSCL config error

27 Error in the SCL configuration file or thefile is missing.

WarningLogic error

28 Too many connections in theconfiguration.

WarningSMT logic error

29 Error in the SMT connections.

WarningGOOSE input error

30 Error in the GOOSE connections.

ACT error 31 Error in the ACT connections.

WarningGOOSE Rx. error

32 Error in the GOOSE message receiving.

WarningAFL error

33 Analog channel configuration error.

WarningUnack card comp.

40 A new composition has not beenacknowledged/accepted.

WarningProtection comm.

50 Error in protection communication.

WarningARC1 cont. light

85 A continuous light has been detected onthe ARC light input 1.





WarningRTD card error,X130

96 Temporary error occurred in RTD cardlocated in slot X130.

WarningRTD meas. error,X130

106 Measurement error in RTD card locatedin slot X130.



For further information on warning indications, see the operation manual.

3.3 LED indication control

The IED includes a global conditioning function LEDPTRC that is used with theprotection indication LEDs.

LED indication control should never be used for tripping purposes.There is a separate trip logic function TRPPTRC available in theIED configuration.

LED indication control is preconfigured in a such way that all the protectionfunction general start and operate signals are combined with this function(available as output signals OUT_START and OUT_OPERATE). These signals arealways internally connected to Start and Trip LEDs. LEDPTRC collects andcombines phase information from different protection functions (available asoutput signals OUT_ST_A /_B /_C and OUT_OPR_A /_B /_C). There isalso combined earth fault information collected from all the earth fault functionsavailable in the IED configuration (available as output signals OUT_ST_NEUT andOUT_OPR_NEUT).

3.4 Programmable LEDs

3.4.1 Function block

GUID-00339108-34E4-496C-9142-5DC69F55EE7A V1 EN

Figure 9: Function block

3.4.2 FunctionalityThe programmable LEDs reside on the right side of the display on the LHMI.



REF615

Overcurrent

Dir. earth-fault

Voltage protection

Phase unbalance

Thermal overload

Breaker failure

Disturb. rec. Triggered

CB condition monitoring

Supervision

Arc detected

Autoreclose shot in progr.

A070704 V3 EN

Figure 10: Programmable LEDs on the right side of the display

All the programmable LEDs in the HMI of the IED have two colors, green and red.For each LED, the different colors are individually controllable.

Each LED has two control inputs, ALARM and OK. The color setting is common forall the LEDs. It is controlled with the Alarm color setting, the default value being"Red". The OK input corresponds to the color that is available, with the defaultvalue being "Green".

Changing the Alarm color setting to "Green" changes the color behavior of the OKinputs to red.

The ALARM input has a higher priority than the OK input.

Each LED is seen in the Application Configuration tool as an individual functionblock. Each LED has user-editable description text for event description. The state("None", "OK", "Alarm") of each LED can also be read under a commonmonitored data view for programmable LEDs.



The LED status also provides a means for resetting the individual LED viacommunication. The LED can also be reset from configuration with the RESET input.

The resetting and clearing function for all LEDs is under the Clear menu.

The menu structure for the programmable LEDs is presented in Figure 11. Thecommon color selection setting Alarm colour for all ALARM inputs is in theGeneral menu, while the LED-specific settings are under the LED-specific menunodes.

Alarm modeDescription

LED 1

Programmable LEDsAlarm color Red

Green

Follow-SFollow-FLatched-SLatchedAck-F-S

Programmable LED description

LED 2

General

GUID-0DED5640-4F67-4112-9A54-E8CAADFFE547 V1 EN

Figure 11: Menu structure

The ALARM input behavior can be selected with the alarm mode settings from thealternatives "Follow-S", "Follow-F", "Latched-S" and "LatchedAck-F-S". The OKinput behavior is always according to "Follow-S". The alarm input latched modescan be cleared with the reset input in the application logic.

GUID-58B6C3F2-873A-4B13-9834-9BB21FCA5704 V1 EN

Figure 12: Symbols used in the sequence diagrams

"Follow-S": Follow Signal, ON

In this mode ALARM follows the input signal value, Non-latched.

Activatingsignal

LEDGUID-952BD571-874A-4572-8710-F0E879678552 V1 EN

Figure 13: Operating sequence "Follow-S"

"Follow-F": Follow Signal, Flashing

Similar to "Follow-S", but instead the LED is flashing when the input is active, Non-latched.



"Latched-S": Latched, ON

This mode is a latched function. At the activation of the input signal, the alarmshows a steady light. After acknowledgement, the alarm disappears.

Activatingsignal

LED

Acknow.GUID-055146B3-780B-43E6-9E06-9FD8D342E881 V1 EN

Figure 14: Operating sequence "Latched-S"

"LatchedAck-F-S": Latched, Flashing-ON

This mode is a latched function. At the activation of the input signal, the alarmstarts flashing. After acknowledgement, the alarm disappears if the signal is notpresent and gives a steady light if the signal is present.

Activatingsignal

LED

Acknow.GUID-1B1414BD-2535-40FA-9642-8FBA4D19BA4A V1 EN

Figure 15: Operating sequence "LatchedAck-F-S"

3.4.3 SignalsTable 40: Input signals

Name Type Default DescriptionOK BOOLEAN 0=False Ok input for LED 1

ALARM BOOLEAN 0=False Alarm input for LED 1

RESET BOOLEAN 0=False Reset input for LED 1

OK BOOLEAN 0=False Ok input for LED 2








Name Type Default DescriptionRESET BOOLEAN 0=False Reset input for LED 3

























3.4.4 SettingsTable 41: LED settings

Parameter Values (Range) Unit Step Default DescriptionAlarm colour 1=Green

2=Red 2=Red Colour for the alarm state of the LED

Alarm mode 0=Follow-S1=Follow-F2=Latched-S3=LatchedAck-F-S

0=Follow-S Alarm mode for programmable LED 1

Description ProgrammableLEDs LED 1







Parameter Values (Range) Unit Step Default DescriptionDescription Programmable

LEDs LED 2Programmable LED description


































Parameter Values (Range) Unit Step Default DescriptionDescription Programmable

LEDs LED 10Programmable LED description





3.4.5 Monitored dataTable 42: Monitored data

Name Type Values (Range) Unit DescriptionProgrammable LED1

Enum 0=None1=Ok3=Alarm

Status of programmableLED 1

Programmable LED2



Programmable LED3



Programmable LED4



Programmable LED5



Programmable LED6



Programmable LED7



Programmable LED8



Programmable LED9



Programmable LED10



Programmable LED11





3.5 Time synchronization

The IED has an internal real-time clock which can be either free-running orsynchronized from an external source. The real-time clock is used for timestamping events, recorded data and disturbance recordings.

The IED is provided with a 48-hour capacitor back-up that enables the real-timeclock to keep time in case of an auxiliary power failure.

Setting Synch Source determines the method how the real-time clock issynchronized. If set to “None”, the clock is free-running and the settings Date andTime can be used to set the time manually. Other setting values activate acommunication protocol that provides the time synchronization. Only onesynchronization method can be active at a time but SNTP provides time masterredundancy.

The IED supports SNTP, IRIG-B, DNP3, Modbus and IEC 60870-5-103 to updatethe real-time clock. IRIG-B with GPS provides the best accuracy, ±1 ms. Theaccuracy using SNTP is +2...3 ms.

When Modbus TCP or DNP3 over TCP/IP is used, SNTP or IRIG-B time synchronization should be used for better synchronizationaccuracy.

When the SNTP server IP setting is changed, the IED must berebooted to activate the new IP address. The SNTP server IPsettings are normally defined in the engineering phase via the SCLfile.

With the legacy protocols, the synchronization message must bereceived within four minutes from the previous synchronization.Otherwise bad synchronisation status is raised for the IED. WithSNTP, it is required that the SNTP server responds to a requestwithin 12 ms, otherwise the response is considered invalid.

The IED can use one of two SNTP servers, the primary or the secondary server.The primary server is mainly in use, whereas the secondary server is used if theprimary server cannot be reached. While using the secondary SNTP server, the IEDtries to switch back to the primary server on every third SNTP request attempt. Ifboth the SNTP servers are offline, event time stamps have the time invalid status.The time is requested from the SNTP server every 60 seconds.

IRIG-B time synchronization requires the IRIG-B format B004/B005 according tothe 200-04 IRIG-B standard. Older IRIG-B standards refer to these as B000/B001with IEEE-1344 extensions. The synchronization time can be either UTC time or



local time. As no reboot is necessary, the time synchronization starts immediatelyafter the IRIG-B sync source is selected and the IRIG-B signal source is connected.

ABB has tested the IRIG-B with the following clock masters:

• Tekron TTM01 GPS clock with IRIG-B output• Meinberg TCG511 controlled by GPS167• Datum ET6000L• Arbiter Systems 1088B

IRIG-B time synchronization requires a COM card with an IRIG-Binput.

When using line differential communication between RED615 IEDs, the timesynchronization messages can be received from the other line end IED within theprotection telegrams. The IED begins to synchronize its real-time clock with theremote end IEDs time if the Line differential time synchronization source isselected. This does not affect the protection synchronization used in the linedifferential protection or the selection of the remote end IEDs time synchronizationmethod. [1]

3.6 Parameter setting groups


GUID-76F71815-D82D-4D81-BCFE-28AF2D56391A V1 EN


3.6.2 FunctionalityThe IED supports six setting groups. Each setting group contains parameterscategorized as group settings inside application functions. The customer canchange the active setting group at run time.

The active setting group can be changed by a parameter or via binary inputsdepending on the mode selected with the Configuration/Setting Group/SGoperation mode setting.

[1] The line differential protection is available only in RED615.



The default value of all inputs is FALSE, which makes it possible to use only therequired number of inputs and leave the rest disconnected. The setting groupselection is not dependent on the SG_x_ACT outputs.

Table 43: Optional operation modes for setting group selection

SG operation mode DescriptionOperator (Default) Setting group can be changed with the setting

Settings/Setting group/Active group.

Logic mode 1 Setting group can be changed with binary inputs(BI_SG_2...BI_SG_6). The highest TRUEbinary input defines the active setting group.

Logic mode 2 Setting group can be changed with binary inputswhere BI_SG_4 is used for selecting settinggroups 1-3 or 4-6.When binary input BI_SG_4 is FALSE, settinggroups 1-3 are selected with binary inputsBI_SG_2 and BI_SG_3. When binary inputBI_SG_4 is TRUE, setting groups 4-6 areselected with binary inputs BI_SG_5 andBI_SG_6.

For example, six setting groups can be controlled with three binary inputs. Set SGoperation mode =”'Logic mode 2” and connect together BI_SG_2 and BI_SG_5same as BI_SG_3 and BI_SG_6.

Table 44: SG operation mode = “Logic mode 1”

Input BI_SG_2 BI_SG_3 BI_SG_4 BI_SG_5 BI_SG_6 Active groupFALSE FALSE FALSE FALSE FALSE 1

TRUE FALSE FALSE FALSE FALSE 2

any TRUE FALSE FALSE FALSE 3

any any TRUE FALSE FALSE 4

any any any TRUE FALSE 5

any any any any TRUE 6

Table 45: SG operation mode = “Logic mode 2”

Input BI_SG_2 BI_SG_3 BI_SG_4 BI_SG_5 BI_SG_6 Active groupFALSE FALSE FALSE any any 1

TRUE FALSE FALSE any any 2

any TRUE FALSE any any 3

any any TRUE FALSE FALSE 4

any any TRUE TRUE FALSE 5

any any TRUE any TRUE 6



The setting group 1 can be copied to any other or all groups from HMI (Copygroup 1).

3.7 Fault records

The IED has the capacity to store the records of 128 latest fault events. Faultrecords include fundamental or RMS current values. The records enable the user toanalyze recent power system events. Each fault record (FLTMSTA) is marked withan up-counting fault number and a time stamp that is taken from the beginning ofthe fault.

The fault recording period begins from the start event of any protection functionand ends if any protection function trips or the start is restored before the operateevent. If a start is restored without an operate event, the start duration shows theprotection function that has started first.

Start duration that has the value of 100% indicates that a protection function hasoperated during the fault and if none of the protection functions has been operated,Start duration shows always values less than 100%.

The Fault recorded data Protection and Start duration is from the same protectionfunction. The Fault recorded data operate time shows the time of the actual faultperiod. This value is the time difference between the activation of the internal startand operate signals. The actual operate time also includes the starting time and thedelay of the output relay.

If some functions in relay application are sensitive to startfrequently it might be advisable to set the setting parameter Trigmode to “From operate”. Then only faults that cause an operateevent trigger a new fault recording.

The fault-related current, voltage, frequency, angle values, shot pointer and theactive setting group number are taken from the moment of the operate event, orfrom the beginning of the fault if only a start event occurs during the fault. Themaximum current value collects the maximum fault currents during the fault. Incase frequency cannot be measured, nominal frequency is used for frequency andzero for Frequency gradient and validity is set accordingly.

Measuring mode for phase current and residual current values can be selected withthe Measurement mode setting parameter.



Table 46: FLTMSTA Non group settings

Parameter Values (Range) Unit Step Default DescriptionOperation 1=on

5=off 1=on Operation Off / On

Trig mode 0=From all faults1=From operate2=From only start

0=From all faults Triggering mode

A measurement mode 1=RMS2=DFT3=Peak-to-Peak

2=DFT Selects used measurement mode phasecurrents and residual current

Table 47: FLTMSTA Monitored data

Name Type Values (Range) Unit DescriptionFault number INT32 0...999999 Fault record number

Time and date Timestamp Fault record time stamp

Start duration FLOAT32 0.00...100.00 % Maximum start durationof all stages during thefault

Operate time FLOAT32 0.000...999999.999

s Operate time

Breaker clear time FLOAT32 0.000...999999.999

s Breaker clear time

Fault distance FLOAT32 0.00...9999.99 pu Distance to faultmeasured in pu

Fault resistance FLOAT32 0.00...999.99 ohm Fault resistance

Fault loop Ris FLOAT32 -1000.00...1000.00

ohm Resistance of fault loop,PHDSTPDIS1

Fault loop React FLOAT32 -1000.00...1000.00

ohm Reactance of fault loop,PHDSTPDIS1

Active group INT32 1...6 Active setting group

Shot pointer INT32 0...7 Autoreclosing shotpointer value

Max diff current IL1 FLOAT32 0.000...80.000 pu Maximum phase Adifferential current

Max diff current IL2 FLOAT32 0.000...80.000 pu Maximum phase Bdifferential current

Max diff current IL3 FLOAT32 0.000...80.000 pu Maximum phase Cdifferential current

Diff current IL1 FLOAT32 0.000...80.000 pu Differential currentphase A

Diff current IL2 FLOAT32 0.000...80.000 pu Differential currentphase B

Diff current IL3 FLOAT32 0.000...80.000 pu Differential currentphase C

Max bias current IL1 FLOAT32 0.000...50.000 pu Maximum phase A biascurrent

Max bias current IL2 FLOAT32 0.000...50.000 pu Maximum phase B biascurrent




Name Type Values (Range) Unit DescriptionMax bias current IL3 FLOAT32 0.000...50.000 pu Maximum phase C bias

current

Bias current IL1 FLOAT32 0.000...50.000 pu Bias current phase A

Bias current IL2 FLOAT32 0.000...50.000 pu Bias current phase B

Bias current IL3 FLOAT32 0.000...50.000 pu Bias current phase C

Diff current Io FLOAT32 0.000...80.000 pu Differential currentresidual

Bias current Io FLOAT32 0.000...50.000 pu Bias current residual

Max current IL1 FLOAT32 0.000...50.000 xIn Maximum phase Acurrent

Max current IL2 FLOAT32 0.000...50.000 xIn Maximum phase Bcurrent

Max current IL3 FLOAT32 0.000...50.000 xIn Maximum phase Ccurrent

Max current Io FLOAT32 0.000...50.000 xIn Maximum residualcurrent

Current IL1 FLOAT32 0.000...50.000 xIn Phase A current

Current IL2 FLOAT32 0.000...50.000 xIn Phase B current

Current IL3 FLOAT32 0.000...50.000 xIn Phase C current

Current Io FLOAT32 0.000...50.000 xIn Residual current

Current Io-Calc FLOAT32 0.000...50.000 xIn Calculated residualcurrent

Current Ps-Seq FLOAT32 0.000...50.000 xIn Positive sequencecurrent

Current Ng-Seq FLOAT32 0.000...50.000 xIn Negative sequencecurrent

Max current IL1B FLOAT32 0.000...50.000 xIn Maximum phase Acurrent (b)

Max current IL2B FLOAT32 0.000...50.000 xIn Maximum phase Bcurrent (b)

Max current IL3B FLOAT32 0.000...50.000 xIn Maximum phase Ccurrent (b)

Max current IoB FLOAT32 0.000...50.000 xIn Maximum residualcurrent (b)

Current IL1B FLOAT32 0.000...50.000 xIn Phase A current (b)

Current IL2B FLOAT32 0.000...50.000 xIn Phase B current (b)

Current IL3B FLOAT32 0.000...50.000 xIn Phase C current (b)

Current IoB FLOAT32 0.000...50.000 xIn Residual current (b)

Current Io-CalcB FLOAT32 0.000...50.000 xIn Calculated residualcurrent (b)

Current Ps-SeqB FLOAT32 0.000...50.000 xIn Positive sequencecurrent (b)

Current Ng-SeqB FLOAT32 0.000...50.000 xIn Negative sequencecurrent (b)

Max current IL1C FLOAT32 0.000...50.000 xIn Maximum phase Acurrent (c)




Name Type Values (Range) Unit DescriptionMax current IL2C FLOAT32 0.000...50.000 xIn Maximum phase B

current (c)

Max current IL3C FLOAT32 0.000...50.000 xIn Maximum phase Ccurrent (c)

Max current IoC FLOAT32 0.000...50.000 xIn Maximum residualcurrent (c)

Current IL1C FLOAT32 0.000...50.000 xIn Phase A current (c)

Current IL2C FLOAT32 0.000...50.000 xIn Phase B current (c)

Current IL3C FLOAT32 0.000...50.000 xIn Phase C current (c)

Current IoC FLOAT32 0.000...50.000 xIn Residual current (c)

Current Io-CalcC FLOAT32 0.000...50.000 xIn Calculated residualcurrent (c)

Current Ps-SeqC FLOAT32 0.000...50.000 xIn Positive sequencecurrent (c)

Current Ng-SeqC FLOAT32 0.000...50.000 xIn Negative sequencecurrent (c)

Voltage UL1 FLOAT32 0.000...4.000 xUn Phase A voltage

Voltage UL2 FLOAT32 0.000...4.000 xUn Phase B voltage

Voltage UL3 FLOAT32 0.000...4.000 xUn Phase C voltage

Voltage U12 FLOAT32 0.000...4.000 xUn Phase A to phase Bvoltage

Voltage U23 FLOAT32 0.000...4.000 xUn Phase B to phase Cvoltage

Voltage U31 FLOAT32 0.000...4.000 xUn Phase C to phase Avoltage

Voltage Uo FLOAT32 0.000...4.000 xUn Residual voltage

Voltage Zro-Seq FLOAT32 0.000...4.000 xUn Zero sequence voltage

Voltage Ps-Seq FLOAT32 0.000...4.000 xUn Positive sequencevoltage

Voltage Ng-Seq FLOAT32 0.000...4.000 xUn Negative sequencevoltage

Voltage UL1B FLOAT32 0.000...4.000 xUn Phase A voltage (b)

Voltage UL2B FLOAT32 0.000...4.000 xUn Phase B voltage (b)

Voltage UL3B FLOAT32 0.000...4.000 xUn Phase B voltage (b)

Voltage U12B FLOAT32 0.000...4.000 xUn Phase A to phase Bvoltage (b)

Voltage U23B FLOAT32 0.000...4.000 xUn Phase B to phase Cvoltage (b)

Voltage U31B FLOAT32 0.000...4.000 xUn Phase C to phase Avoltage (b)

Voltage UoB FLOAT32 0.000...4.000 xUn Residual voltage (b)

Voltage Zro-SeqB FLOAT32 0.000...4.000 xUn Zero sequence voltage(b)

Voltage Ps-SeqB FLOAT32 0.000...4.000 xUn Positive sequencevoltage (b)




Name Type Values (Range) Unit DescriptionVoltage Ng-SeqB FLOAT32 0.000...4.000 xUn Negative sequence

voltage (b)

PTTR thermal level FLOAT32 0.00...99.99 PTTR calculatedtemperature of theprotected object relativeto the operate level

PDNSPTOC1 rat. I2/I1

FLOAT32 0.00...999.99 % PDNSPTOC1 ratio I2/I1

Frequency FLOAT32 30.00...80.00 Hz Frequency

Frequency gradient FLOAT32 -10.00...10.00 Hz/s Frequency gradient

Conductance Yo FLOAT32 -1000.00...1000.00

mS Conductance Yo

Susceptance Yo FLOAT32 -1000.00...1000.00

mS Susceptance Yo

Angle Uo - Io FLOAT32 -180.00...180.00 deg Angle residual voltage -residual current

Angle U23 - IL1 FLOAT32 -180.00...180.00 deg Angle phase B to phaseC voltage - phase Acurrent

Angle U31 - IL2 FLOAT32 -180.00...180.00 deg Angle phase C to phaseA voltage - phase Bcurrent

Angle U12 - IL3 FLOAT32 -180.00...180.00 deg Angle phase A to phaseB voltage - phase Ccurrent

Angle UoB - IoB FLOAT32 -180.00...180.00 deg Angle residual voltage -residual current (b)

Angle U23B - IL1B FLOAT32 -180.00...180.00 deg Angle phase B to phaseC voltage - phase Acurrent (b)

Angle U31B - IL2B FLOAT32 -180.00...180.00 deg Angle phase C to phaseA voltage - phase Bcurrent (b)

Angle U12B - IL3B FLOAT32 -180.00...180.00 deg Angle phase A to phaseB voltage - phase Ccurrent (b)

3.8 Non-volatile memory

In addition to the setting values, the IED can store some data in the non-volatilememory.

• Up to 1024 events are stored. The stored events are visible in LHMI andWHMI only.

• Recorded data



• Fault records (up to 128)• Maximum demands

• Circuit breaker condition monitoring• Latched alarm and trip LEDs' status• Trip circuit lockout• Counter values

3.9 Binary input

3.9.1 Binary input filter timeThe filter time eliminates debounces and short disturbances on a binary input. Thefilter time is set for each binary input of the IED.

1 2

3

4

5 5

GUID-13DA5833-D263-4E23-B666-CF38B1011A4B V1 EN

Figure 17: Binary input filtering

1 t0

2 t1

3 Input signal

4 Filtered input signal

5 Filter time

At the beginning, the input signal is at the high state, the short low state is filteredand no input state change is detected. The low state starting from the time t0exceeds the filter time, which means that the change in the input state is detectedand the time tag attached to the input change is t0. The high state starting from t1 isdetected and the time tag t1 is attached.

Each binary input has a filter time parameter Input # filter, where # is the numberof the binary input of the module in question (for example Input 1 filter).



Table 48: Input filter parameter values

Parameter Values DefaultInput # filter time 5...1000 ms 5 ms

3.9.2 Binary input inversionThe parameter Input # invert is used to invert a binary input.

Table 49: Binary input states

Control voltage Input # invert State of binary inputNo 0 False (0)

Yes 0 True (1)

No 1 True (0)

Yes 1 False (0)

When a binary input is inverted, the state of the input is TRUE (1) when no controlvoltage is applied to its terminals. Accordingly, the input state is FALSE (0) whena control voltage is applied to the terminals of the binary input.

3.9.3 Oscillation suppressionOscillation suppression is used to reduce the load from the system when a binaryinput starts oscillating. A binary input is regarded as oscillating if the number ofvalid state changes (= number of events after filtering) during one second is equalto or greater than the set oscillation level value. During oscillation, the binary inputis blocked (the status is invalid) and an event is generated. The state of the inputwill not change when it is blocked, that is, its state depends on the condition beforeblocking.

The binary input is regarded as non-oscillating if the number of valid state changesduring one second is less than the set oscillation level value minus the setoscillation hysteresis value. Note that the oscillation hysteresis must be set lowerthan the oscillation level to enable the input to be restored from oscillation. Whenthe input returns to a non-oscillating state, the binary input is deblocked (the statusis valid) and an event is generated.

Table 50: Oscillation parameter values

Parameter Values DefaultInput osc. level 2...50 events/s 30 events/s

Input osc. hyst 2...50 events/s 10 events/s



3.10 RTD/mA inputs

3.10.1 FunctionalityRTD and mA analog input module is used for monitoring and metering milli-ampere (mA), temperature (°C) and resistance (Ω). Each input can be linearlyscaled for various applications, for example, transformer’s tap changer positionindication. Each input has independent limit value supervision and deadbandsupervision functions, including warning and alarm signals.

3.10.2 Operation principleAll the inputs of the module are independent RTD and mA channels withindividual protection, reference and optical isolation for each input, making themgalvanically isolated from each other and from the rest of the module. However,the RTD inputs share a common ground.

3.10.2.1 Selection of input signal type

The function module inputs accept current or resistance type signals. The inputs areconfigured for a particular type of input type by the channel specific Input modesetting. The default value for all inputs is “Not in use”, which means that thechannel is not sampled at all, and the output value quality is set accordingly.

Table 51: Limits for the RTD/mA inputs

Input mode DescriptionNot in use Default selection. Used when the corresponding input is not used.

0...20 mA Selection for analog DC milli-ampere current inputs in the input range of 0 – 20 mA.

Resistance Selection for RTD inputs in the input range of 0 – 2000 Ω.

Pt100Pt250Ni100Ni120Ni250Cu10

Selection for RTD inputs, when temperature sensor is used. All the selectablesensor types have their resistance vs. temperature characteristics stored in themodule; default measuring range is -40 – 200 °C.

3.10.2.2 Selection of output value format

Each input has independent Value unit settings that are used to select the unit forthe channel output. The default value for the Value unit setting is “Dimensionless”.Input minimum and Input maximum, and Value maximum and Value minimumsettings have to be adjusted according to the input channel. The default values forthese settings are set to their maximum and minimum setting values.

When the channel is used for temperature sensor type, set the Value unit setting to“Degrees celsius”. When Value unit is set to “Degrees celsius”, the linear scaling is



not possible, but the default range (-40…200 °C) can be set smaller with the Valuemaximum and Value minimum settings.

When the channel is used for DC milli-ampere signal and the application requireslinear scaling of the input range, set the Value unit setting to “Dimensionless”,where the input range can be linearly scaled with settings Input minimum and Inputmaximum to Value minimum and Value maximum. When milli-ampere is used as anoutput unit, set the Value unit setting to “Ampere”. When Value unit is set to“Ampere”, the linear scaling is not possible, but the default range (0…20 mA) canbe set smaller with Value maximum and Value minimum settings.

When the channel is used for resistance type signals and the application requireslinear scaling of the input range, set the Value unit setting to “Dimensionless”,where the input range can be linearly scaled with the setting Input minimum andInput maximum to Value minimum and Value maximum. When resistance is used asan output unit, set the Value unit setting to “Ohm”. When Value unit is set to“Ohm”, the linear scaling is not possible, but the default range (0…2000 Ω) can beset smaller with the Value maximum and Value minimum settings.

3.10.2.3 Input linear scaling

Each RTD/mA input can be scaled linearly by the construction of a linear outputfunction in respect to the input. The curve consists of two points, where the y-axis(Input minimum and Input maximum) defines the input range and the x-axis (Valueminimum and Value maximum) is the range of the scaled value of the input.

The input scaling can be bypassed by selecting Value unit = "Ohm"when Input mode = "Resistance" is used and by selecting Value unit= "Ampere" when Input mode = "0...20 mA" is used.

Example for linear scalingMilli-ampere input is used as tap changer position information. The sensorinformation is from 4 mA to 20 mA that is equivalent to the tap changer positionfrom -36 to 36, respectively.



Input maximum

Input minimum

Input mode”0..20mA”

4 mA

20 mA

Value minimum-36

AI_VAL#

Value maximum36

Value unit”Dimensionless”

X130-Input#

GUID-85338A5E-3D2F-4031-A598-EA8A525190D3 V1 EN

Figure 18: Milli-ampere input scaled to tap changer position information

3.10.2.4 Measurement chain supervision

Each input contains functionality to monitor the input measurement chain. Thecircuitry monitors the RTD channels continuously and reports a circuitry break ofany enabled input channel. If the measured input value is outside the limits, minimum/maximum value is shown in the corresponding output. The quality of thecorresponding output is set accordingly to indicate misbehavior in the RTD/mA input.

Table 52: Function identification, limits for the RTD/mA inputs

Input Limit valueRTD temperature, high > 200 °C

RTD temperature, low < -40 °C

mA current, high > 23 mA

Resistance, high > 2000 Ω

3.10.2.5 Selfsupervision

Each input sample is validated before it is fed into the filter algorithm. The samplesare validated by measuring an internally set reference current immediately after theinputs are sampled. Each RTD sensor type has expected current based on thesensor type. If the measured offset current deviates from the reference current morethan 20%, the sample is discarded and the output is set to invalid. The invalidmeasure status deactivates as soon as the measured input signal is within themeasurement offset.

3.10.2.6 Calibration

RTD and mA inputs are calibrated at the factory. The calibration circuitry monitorsthe RTD channels continuously and reports a circuitry break of any channel.



3.10.2.7 Limit value supervision

The limit value supervision function indicates whether the measured value ofAI_INST# exceeds or falls below the set limits. All the measuring channels havean individual limit value supervision function. The measured value contains thecorresponding range information AI_RANGE# and has a value in the range of 0 to4:

• 0: “normal”• 1: “high”• 2: “low”• 3: “high-high”• 4: “low-low”

The range information changes and the new values are reported.

AI_RANGE#=1

AI_RANGE#=3

AI_RANGE#=0

Hysteresis

Val high high limit

Val high limit

Val low limit

Val low low limit

AI_RANGE#=2

AI_RANGE#=4

Y

tAI_RANGE#=0

Value Reported

Value maximum

Value minimum

Out of Range

GUID-6A6033E6-22C8-415D-AABD-D0556D38C986 V1 EN

Figure 19: Limit value supervision for RTD (X130)

The range information of “High-high limit” and “Low-low limit” is combined fromall measurement channels to the Boolean ALARM output. The range informationof “High limit” and “Low limit” is combined from all measurement channels toBoolean WARNING output.

Table 53: Settings for X130 (RTD) analog input limit value supervision

Function Settings for limit value supervisionX130 (RTD) analog input Out of range Value maximum

High-high limit Val high high limit

High limit Val high limit

Low limit Val low limit

Low-low limit Val low low limit

Out of range Value minimum



When the measured value exceeds either the Value maximum setting or the Valueminimum setting, the corresponding quality is set to out of range and a maximumor minimum value is shown when the measured value exceeds the addedhysteresis, respectively. The hysteresis is added to the extreme value of the rangelimit to allow the measurement slightly to exceed the limit value before it isconsidered as out of range.

3.10.2.8 Deadband supervision

Each input has an independent deadband supervision. The deadband supervisionfunction reports the measured value according to integrated changes over a timeperiod.

GUID-63CA9A0F-24D8-4BA8-A667-88632DF53284 V1 EN

Figure 20: Integral deadband supervision

The deadband value used in the integral calculation is configured with the Valuedeadband setting. The value represents the percentage of the difference betweenthe maximum and minimum limits in the units of 0.001 percent * seconds. Thereporting delay of the integral algorithms in seconds is calculated with the formula:

t sY

( )(

=×

∆ ×

Value maximum - Value minimum) deadband / 1000

1000%

GUID-CC447162-C1B4-4E74-A253-828F388266EB V1 EN (Equation )

Example of X130 (RTD) analog input deadband supervisionTemperature sensor Pt100 is used in the temperature range of 15...180 °C. Valueunit “Degrees Celsius” is used and the set values Value minimum and Valuemaximum are set to 15 and 180, respectively.

Value deadband = 7500 (7,5% of the total measuring range 165)

AI_VAL# = AI_DB# = 85

If AI_VAL# changes to 90, the reporting delay is:



t s s( )( ) /

%,=

− ×

− ×≈

180 15 7500 1000

90 85 1002 5

GUID-F47EF6B6-9A14-44A2-AD19-BC067E4A7D78 V1 EN (Equation )

Table 54: Settings for X130 (RTD) analog input deadband supervision

Function Setting Maximum/minimum (=range)X130 (RTD) analog input Value deadband Value maximum / Value minimum

(=20000)

Since the function can be utilized in various measurement modes,the default values are set to the extremes; thus, it is very importantto set correct limit values to suit the application before thedeadband supervision works properly.

3.10.2.9 RTD temperature vs. resistance

Table 55: Temperature vs. resistance

Temp°C

Platinum TCR 0.00385 Nickel TCR 0.00618 Copper TCR0.00427

Pt 100 Pt 250 Ni 100 Ni 120 Ni 250 Cu 10-40 84.27 210.675 79.1 94.92 197.75 7.49

-30 88.22 220.55 84.1 100.92 210.25 -

-20 92.16 230.4 89.3 107.16 223.25 8.263

-10 96.09 240.225 94.6 113.52 236.5 -

0 100 250 100 120 250 9.035

10 103.9 259.75 105.6 126.72 264 -

20 107.79 269.475 111.2 133.44 278 9.807

30 111.67 279.175 117.1 140.52 292.75 -

40 115.54 288.85 123 147.6 307.5 10.58

50 119.4 298.5 129.1 154.92 322.75 -

60 123.24 308.1 135.3 162.36 338.25 11.352

70 127.07 317.675 141.7 170.04 354.25 -

80 130.89 327.225 148.3 177.96 370.75 12.124

90 134.7 336.75 154.9 185.88 387.25 -

100 138.5 346.25 161.8 194.16 404.5 12.897

120 146.06 365.15 176 211.2 440 13.669

140 153.58 383.95 190.9 229.08 477.25 14.442

150 - - 198.6 238.32 496.5 -

160 161.04 402.6 206.6 247.92 516.5 15.217

180 168.46 421.15 223.2 267.84 558 -

200 175.84 439.6 240.7 288.84 601.75 -



3.10.2.10 RTD/mA input connection

RTD inputs can be used with 2-wire or 3-wire connection with common ground.When using the 3-wire connection, it is important that all three wires connectingthe sensor are symmetrical, that is, the wires are of the same type and length, hencethe wire resistance is automatically compensated.

GUID-BC4182F7-F701-4E09-AB3D-EFB48280F097 V1 EN

Figure 21: Three RTD/resistance sensors connected according to the 3-wireconnection



GUID-2702C0B0-99CF-40D0-925C-BEC0725C0E97 V1 EN

Figure 22: Three RTD/resistance sensors connected according to the 2-wireconnection

X130

+

-

1

2

11

12.........

TransducerSensor

Shunt(44 Ω)

...

......

GUID-88E6BD08-06B8-4ED3-B937-4CC549697684 V1 EN

Figure 23: mA wiring connection



3.10.3 SignalsTable 56: X130 (RTD/mA) analog input signals

Name Type DescriptionALARM BOOLEAN General alarm

WARNING BOOLEAN General warning

AI_VAL1 FLOAT32 mA input, Connectors 1-2, instantaneous value

AI_VAL2 FLOAT32 mA input, Connectors 3-4, instantaneous value

AI_VAL3 FLOAT32 RTD input, Connectors 5-6-11c, instantaneousvalue






3.10.4 SettingsTable 57: RTD input settings

Parameter Values (Range) Unit Step Default DescriptionInput mode 1=Not in use

2=Resistance10=Pt10011=Pt25020=Ni10021=Ni12022=Ni25030=Cu10

1=Not in use Analogue input mode

Input maximum 0...2000 1 2000 Maximum analogue input value for mAor resistance scaling

Input minimum 0...2000 1 0 Minimum analogue input value for mA orresistance scaling

Value unit 1=Dimensionless5=Ampere23=Degreescelsius30=Ohm

1=Dimensionless Selected unit for output value format

Value maximum -10000.0...10000.0 10000.0 Maximum output value for scaling andsupervision

Value minimum -10000.0...10000.0 -10000.0 Minimum output value for scaling andsupervision

Val high high limit -10000.0...10000.0 10000.0 Output value high alarm limit forsupervision




Parameter Values (Range) Unit Step Default DescriptionValue high limit -10000.0...10000.0 10000.0 Output value high warning limit for

supervision

Value low limit -10000.0...10000.0 -10000.0 Output value low warning limit forsupervision

Value low low limit -10000.0...10000.0 -10000.0 Output value low alarm limit forsupervision

Value deadband 100...100000 1000 Deadband configuration value forintegral calculation. (percentage ofdifference between min and max as0,001 % s)

Table 58: mA input settings

Parameter Values (Range) Unit Step Default DescriptionInput mode 1=Not in use

5=0..20mA 1=Not in use Analogue input mode

Input maximum 0...20 1 20 Maximum analogue input value for mAor resistance scaling

Input minimum 0...20 1 0 Minimum analogue input value for mA orresistance scaling

Value unit 1=Dimensionless5=Ampere23=Degreescelsius30=Ohm

1=Dimensionless Selected unit for output value format

Value maximum -10000.0...10000.0 10000.0 Maximum output value for scaling andsupervision

Value minimum -10000.0...10000.0 -10000.0 Minimum output value for scaling andsupervision

Val high high limit -10000.0...10000.0 10000.0 Output value high alarm limit forsupervision

Value high limit -10000.0...10000.0 10000.0 Output value high warning limit forsupervision

Value low limit -10000.0...10000.0 -10000.0 Output value low warning limit forsupervision

Value low low limit -10000.0...10000.0 -10000.0 Output value low alarm limit forsupervision

Value deadband 100...100000 1000 Deadband configuration value forintegral calculation. (percentage ofdifference between min and max as0,001 % s)



Table 59: X130 (RTD/mA) monitored data

Name Type Values (Range) Unit DescriptionAI_DB1 FLOAT32 -10000.0...10000

.0 mA input, Connectors

1-2, reported value

AI_RANGE1 Enum 0=normal1=high2=low3=high-high4=low-low

mA input, Connectors1-2, range

AI_DB2 FLOAT32 -10000.0...10000.0

mA input, Connectors3-4, reported value


mA input, Connectors3-4, range

AI_DB3 FLOAT32 -10000.0...10000.0

RTD input, Connectors5-6-11c, reported value


RTD input, Connectors5-6-11c, range

AI_DB4 FLOAT32 -10000.0...10000.0




AI_DB5 FLOAT32 -10000.0...10000.0




AI_DB6 FLOAT32 -10000.0...10000.0

RTD input, Connectors13-14-12c, reportedvalue



AI_DB7 FLOAT32 -10000.0...10000.0





Name Type Values (Range) Unit DescriptionAI_RANGE7 Enum 0=normal

1=high2=low3=high-high4=low-low


AI_DB8 FLOAT32 -10000.0...10000.0




3.11 GOOSE function blocks

GOOSE function blocks are used for connecting incoming GOOSE data toapplication. They support BOOLEAN, Dbpos, Enum, FLOAT32, INT8 and INT32data types.

Common signalsThe VALID output indicates the validity of received GOOSE data, which means incase of valid, that the GOOSE communication is working and received data qualitybits (if configured) indicate good process data. Invalid status is caused either bybad data quality bits or GOOSE communication failure. See IEC 61850engineering guide for details.

The OUT output passes the received GOOSE value for the application. Defaultvalue (0) is used if VALID output indicates invalid status. The IN input is definedin the GOOSE configuration and can always be seen in SMT sheet.

SettingsThe GOOSE function blocks do not have any parameters available in LHMI orPCM600.

3.11.1 GOOSERCV_BIN function block

3.11.1.1 Function block

GUID-44EF4D6E-7389-455C-BDE5-B127678E2CBC V1 EN




3.11.1.2 Functionality

The GOOSERCV_BIN function is used to connect the GOOSE binary inputs to theapplication.

3.11.1.3 Signals

Table 60: GOOSERCV_BIN Input signals

Name Type Default DescriptionIN BOOLEAN 0 Input signal

Table 61: GOOSERCV_BIN Output signals

Name Type DescriptionOUT BOOLEAN Output signal

VALID BOOLEAN Output signal

3.11.2 GOOSERCV_DP function block


GUID-63C0C3EE-1C0E-4F78-A06E-3E84F457FC98 V1 EN



The GOOSERCV_DP function is used to connect the GOOSE double binary inputsto the application.

3.11.2.3 Signals

Table 62: GOOSERCV_DP Input signals

Name Type Default DescriptionIN Dbpos 00 Input signal

Table 63: GOOSERCV_DP Output signals

Name Type DescriptionOUT Dbpos Output signal




3.11.3 GOOSERCV_MV function block


GUID-A59BAF25-B9F8-46EA-9831-477AC665D0F7 V1 EN



The GOOSERCV_MV function is used to connect the GOOSE measured valueinputs to the application.

3.11.3.3 Signals

Table 64: GOOSERCV_MV Input signals

Name Type Default DescriptionIN FLOAT32 0 Input signal

Table 65: GOOSERCV_MV Output signals

Name Type DescriptionOUT FLOAT32 Output signal


3.11.4 GOOSERCV_INT8 function block


GUID-B4E1495B-F797-4CFF-BD19-AF023EA2D3D9 V1 EN



The GOOSERCV_INT8 function is used to connect the GOOSE 8 bit integerinputs to the application.



3.11.4.3 Signals

Table 66: GOOSERCV_INT8 Input signals

Name Type DescriptionIN INT8 Input signal

Table 67: GOOSERCV_INT8 Output signals

Name Type DescriptionOUT INT8 Output signal


3.11.5 GOOSERCV_INTL function block


GUID-241A36E0-1BB9-4323-989F-39668A7B1DAC V1 EN



The GOOSERCV_INTL function is used to connect the GOOSE double binaryinput to the application and extracting single binary position signals from thedouble binary position signal.

The OP output signal indicates that the position is open. Default value (0) is used ifVALID output indicates invalid status.

The CL output signal indicates that the position is closed. Default value (0) is usedif VALID output indicates invalid status.

The OK output signal indicates that the position is neither in faulty or intermediatestate. The default value (0) is used if VALID output indicates invalid status.

3.11.5.3 Signals

Table 68: GOOSERCV_INTL Input signals

Name Type Default DescriptionIN Dbpos 00 Input signal



Table 69: GOOSERCV_INTL Output signals

Name Type DescriptionOP BOOLEAN Position open output signal

CL BOOLEAN Position closed output signal

OK BOOLEAN Position OK output signal


3.11.6 GOOSERCV_CMV function block


GUID-4C3F3A1A-F5D1-42E1-840F-6106C58CB380 V1 EN



The GOOSERCV_CMV function is used to connect GOOSE measured valueinputs to the application. The MAG_IN (amplitude) and ANG_IN (angle) inputsare defined in the GOOSE configuration (PCM600).

The MAG output passes the received GOOSE (amplitude) value for theapplication. Default value (0) is used if VALID output indicates invalid status.

The ANG output passes the received GOOSE (angle) value for the application.Default value (0) is used if VALID output indicates invalid status.

3.11.6.3 Signals

Table 70: GOOSERCV_CMV Input signals

Name Type Default DescriptionMAG_IN FLOAT32 0 Input signal

(amplitude)

ANG_IN FLOAT32 0 Input signal (angle)

Table 71: GOOSERCV_CMV Output signals

Name Type DescriptionMAG FLOAT32 Output signal (amplitude)

ANG FLOAT32 Output signal (angle)




3.11.7 GOOSERCV_ENUM function block


GUID-E1AE8AD3-ED99-448A-8C11-558BCA68CDC4 V1 EN



The GOOSERCV_ENUM function block is used to connect GOOSE enumeratorinputs to the application.

3.11.7.3 Signals

Table 72: GOOSERCV_ENUM Input signals

Name Type Default DescriptionIN Enum 0 Input signal

Table 73: GOOSERCV_ENUM Output signals

Name Type DescriptionOUT Enum Output signal


3.11.8 GOOSERCV_INT32 function block


GUID-61FF1ECC-507D-4B6D-8CA5-713A59F58D5C V1 EN



The GOOSERCV_INT32 function block is used to connect GOOSE 32 bit integerinputs to the application.



3.11.8.3 Signals

Table 74: GOOSERCV_INT32 Input signals

Name Type Default DescriptionIN INT32 0 Input signal

Table 75: GOOSERCV_INT32 Output signals

Name Type DescriptionOUT INT32 Output signal


3.12 Type conversion function blocks

3.12.1 QTY_GOOD function block


GUID-1999D6D9-4517-4FFE-A14D-08FDB5E8B9F6 V1 EN



The QTY_GOOD function block evaluates the quality bits of the input signal andpasses it as a Boolean signal for the application.

The IN input can be connected to any logic application signal (logic functionoutput, binary input, application function output or received GOOSE signal). Dueto application logic quality bit propagation, each (simple and even combined)signal has quality which can be evaluated.

The OUT output indicates quality good of the input signal. Input signals that haveno quality bits set or only test bit is set, will indicate quality good status.

3.12.1.3 Signals

Table 76: QTY_GOOD Input signals

Name Type Default DescriptionIN Any 0 Input signal



Table 77: QTY_GOOD Output signals


3.12.2 QTY_BAD function block

3.12.2.1 Fucntion block

GUID-8C120145-91B6-4295-98FB-AE78430EB532 V1 EN



The QTY_BAD function block evaluates the quality bits of the input signal andpasses it as a Boolean signal for the application.

The IN input can be connected to any logic application signal (logic functionoutput, binary input, application function output or received GOOSE signal). Dueto application logic quality bit propagation, each (simple and even combined)signal has quality which can be evaluated.

The OUT output indicates quality bad of the input signal. Input signals that haveany other than test bit set, will indicate quality bad status.

3.12.2.3 Signals

Table 78: QTY_BAD Input signals


Table 79: QTY_BAD Output signals




3.12.3 QTY_GOOSE_COMM function block


The QTY_GOOSE_COMM function block evaluates the peer IED communicationstatus from the quality bits of the input signal and passes it as a Boolean signal tothe application.

The IN input can be connected to any GOOSE application logic output signal, forexample, GOOSERCV_BIN.

The OUT output indicates the communication status of the GOOSE function block.When the output is in the true (1) state, the GOOSE communication is active. Thevalue false (0) indicates communication timeout.

3.12.3.2 Signals

Table 80: QTY_GOOSE_COMM Input signals


Table 81: QTY_GOOSE_COMM Output signals


3.12.4 T_HEALTH function block


GUID-B5FCAE66-8026-4D5F-AC38-028E5A8171BB V1 EN



The T_HEALTH function evaluates enumerated data of “Health” data attribute.This function block can only be used with GOOSE.

The IN input can be connected to GOOSERCV_ENUM function block, which isreceiving the LD0.LLN0.Health.stVal data attribute sent by another IED.



The outputs OK, WARNING and ALARM are extracted from the enumerated inputvalue. Only one of the outputs can be active at a time. In case theGOOSERCV_ENUM function block doesn't receive the value from the sendingIED, the default value (0) is used and the ALARM is activated in the T_HEALTHfunction block.

3.12.4.3 Signals

Table 82: T_HEALTH Input signals


Table 83: T_HEALTH Output signals

Name Type DescriptionOK BOOLEAN Output signal

WARNING BOOLEAN Output signal

ALARM BOOLEAN Output signal

3.12.5 T_F32_INT8 function block


GUID-F0F44FBF-FB56-4BC2-B421-F1A7924E6B8C V1 EN



T_F32_INT8 is a type conversion function.

The function converts 32-bit floating type values to 8-bit integer type. Therounding operation is included. Output value saturates if the input value is belowthe minimum or above the maximum value.

3.12.5.3 Signals

Table 84: T_F32_INT8 Input signals

Name Type Default DescriptionF32 FLOAT32 0.0 Input signal



Table 85: T_F32_INT8 Output signal

Name Type DescriptionINT8 INT8 Output signal

3.12.5.4 Settings

The function does not have any parameters available in LHMI or Protection andControl IED Manager (PCM600).

3.12.6 T_DIR function block


The T_DIR function evaluates enumerated data of the FAULT_DIR data attributeof the directional functions. T_DIR can only be used with GOOSE. The DIR inputcan be connected to the GOOSERCV_ENUM function block, which is receivingthe LD0.<function>.Str.dirGeneral or LD0.<function>.Dir.dirGeneral data attributesent by another IED.

The outputs FWD and REV are extracted from the enumerated input value.

3.12.6.2 Signals

Table 86: T_DIR Input signals

Name Type Default DescriptionDIR Enum 0 Input signal

Table 87: T_DIR Output signals

Name Type Default DescriptionFWD BOOLEAN 0 Direction forward

REV BOOLEAN 0 Direction backward



3.13 Configurable logic blocks

3.13.1 Standard configurable logic blocks

3.13.1.1 OR function block

Function block

GUID-9D001113-8912-440D-B206-051DED17A23C V1 EN

Figure 36: Function blocks

FunctionalityOR and OR6 are used to form general combinatory expressions with Booleanvariables.

The O output is activated when at least one input has the value TRUE. The defaultvalue of all inputs is FALSE, which makes it possible to use only the requirednumber of inputs and leave the rest disconnected.

OR has two inputs and OR6 has six inputs.

Signals

Table 88: OR Input signals

Name Type Default DescriptionB1 BOOLEAN 0 Input signal 1

B2 BOOLEAN 0 Input signal 2

Table 89: OR6 Input signals









Table 90: OR Output signal

Name Type DescriptionO BOOLEAN Output signal

Table 91: OR6 Output signal


SettingsThe function does not have any parameters available in LHMI or Protection andControl IED Manager (PCM600).

3.13.1.2 AND function block

Function block

GUID-7592F296-60B5-4414-8E17-2F641316CA43 V1 EN


FunctionalityAND and AND6 are used to form general combinatory expressions with Booleanvariables.

The default value in all inputs is logical true, which makes it possible to use onlythe required number of inputs and leave the rest disconnected.

AND has two inputs and AND6 has six inputs.

Signals

Table 92: AND Input signals





Table 93: AND6 Input signals







Table 94: AND Output signal


Table 95: AND6 Output signal



3.13.1.3 XOR function block

Function block

GUID-9C247C8A-03A5-4F08-8329-F08BE7125B9A V1 EN


FunctionalityThe exclusive OR function XOR is used to generate combinatory expressions withBoolean variables.

The output signal is TRUE if the input signals are different and FALSE if they areequal.



Signals

Table 96: XOR Input signals



Table 97: XOR Output signal



3.13.1.4 NOT function block

Function block

GUID-0D0FC187-4224-433C-9664-908168EE3626 V1 EN


FunctionalityNOT is used to generate combinatory expressions with Boolean variables.

NOT inverts the input signal.

Signals

Table 98: NOT Input signal

Name Type Default DescriptionI BOOLEAN 0 Input signal

Table 99: NOT Output signal





3.13.1.5 MAX3 function block

Function block

GUID-5454FE1C-2947-4337-AD58-39D266E91993 V1 EN


FunctionalityThe maximum function MAX3 selects the maximum value from three analog values.

The disconnected inputs have the value 0.

Signals

Table 100: MAX3 Input signals

Name Type Default DescriptionIN1 FLOAT32 0 Input signal 1

IN2 FLOAT32 0 Input signal 2


Table 101: MAX3 Output signal



3.13.1.6 MIN3 function block

Function block

GUID-40218B77-8A30-445A-977E-46CB8783490D V1 EN


FunctionalityThe minimum function MIN3 selects the minimum value from three analog values.



If the minimum value is to be selected from two signals, connecting one of theinputs to two in MIN3 makes all the inputs to be connected.

Signals

Table 102: MIN3 Input signals

Name Type Default DescriptionIN1 FLOAT32 0 Input signal 1



Table 103: MIN3 Output signal



3.13.1.7 R_TRIG function block

Function block

GUID-3D0BBDC3-4091-4D8B-A35C-95F6289E6FD8 V1 EN


FunctionalityR_Trig is used as a rising edge detector.

R_Trig detects the transition from FALSE to TRUE at the CLK input. When therising edge is detected, the element assigns the output to TRUE. At the nextexecution round, the output is returned to FALSE despite the state of the input.

Signals

Table 104: R_TRIG Input signals

Name Type Default DescriptionCLK BOOLEAN 0 Input signal



Table 105: R_TRIG Output signal

Name Type DescriptionQ BOOLEAN Output signal


3.13.1.8 F_TRIG function block

Function block

GUID-B47152D2-3855-4306-8F2E-73D8FDEC4C1D V1 EN


FunctionalityF_Trig is used as a falling edge detector.

The function detects the transition from TRUE to FALSE at the CLK input. Whenthe falling edge is detected, the element assigns the Q output to TRUE. At the nextexecution round, the output is returned to FALSE despite the state of the input.

Signals

Table 106: F_TRIG Input signals

Name Type Default DescriptionCLK BOOLEAN 0 Input signal

Table 107: F_TRIG Output signal

Name Type DescriptionQ BOOLEAN Output signal




3.13.1.9 T_POS_XX function blocks

Function block

GUID-4548B304-1CCD-454F-B819-7BC9F404131F V1 EN


FunctionalityThe circuit breaker position information can be communicated with the IEC 61850GOOSE messages. The position information is a double binary data type which isfed to the POS input.

T_POS_CL and T_POS_OP are used for extracting the circuit breaker statusinformation. Respectively, T_POS_OK is used to validate the intermediate orfaulty breaker position.

Table 108: Cross reference between circuit breaker position and the output of the function block

Circuit breaker position Output of the function block T_POS_CL T_POS_OP T_POS_OKIntermediate '00' FALSE FALSE FALSE

Close '01' TRUE FALSE TRUE

Open '10' FALSE TRUE TRUE

Faulty '11' TRUE TRUE FALSE

Signals

Table 109: T_POS_CL Input signals

Name Type Default DescriptionPOS Double binary 0 Input signal

Table 110: T_POS_OP Input signals


Table 111: T_POS_OK Input signals




Table 112: T_POS_CL Output signal

Name Type DescriptionCLOSE BOOLEAN Output signal

Table 113: T_POS_OP Output signal

Name Type DescriptionOPEN BOOLEAN Output signal

Table 114: T_POS_OK Output signal

Name Type DescriptionOK BOOLEAN Output signal


3.13.1.10 SWITCHR function block

Function block

GUID-63F5ED57-E6C4-40A2-821A-4814E1554663 V1 EN


FunctionalitySWITCHR switching block for REAL data type is operated by the CTL_SW input,selects the output value OUT between the IN1 and IN2 inputs.

CTL_SW OUTFALSE IN2

TRUE IN1

Signals

Table 115: SWITCHR Input signals

Name Type Default DescriptionCTL_SW BOOLEAN 1 Control Switch

IN1 REAL 0.0 Real input 1

IN2 REAL 0.0 Real input 2



Table 116: SWITCHR Output signals

Name Type DescriptionOUT REAL Real switch output

3.13.2 Minimum pulse timer

3.13.2.1 Minimum pulse timer TPGAPC

Function block

GUID-809F4B4A-E684-43AC-9C34-574A93FE0EBC V1 EN


FunctionalityThe Minimum pulse timer TPGAPC function contains two independent timers. Thefunction has a settable pulse length (in milliseconds). The timers are used forsetting the minimum pulse length for example, the signal outputs. Once the input isactivated, the output is set for a specific duration using the Pulse time setting.

GUID-8196EE39-3529-46DC-A161-B1C40224559F V1 EN

Figure 47: A = Trip pulse is shorter than Pulse time setting, B = Trip pulse islonger than Pulse time setting

Signals

Table 117: TPGAPC Output signals

Name Type DescriptionOUT1 BOOLEAN Output 1 status

OUT2 BOOLEAN Output 2 status



Settings

Table 118: TPGAPC Non group settings

Parameter Values (Range) Unit Step Default DescriptionPulse time 0...60000 ms 1 150 Minimum pulse time

3.13.2.2 Minimum pulse timer TPSGAPC

Function block

GUID-F9AACAF7-2183-4315-BE6F-CD53618009C0 V1 EN


FunctionalityThe Minimum second pulse timer function TPSGAPC contains two independenttimers. The function has a settable pulse length (in seconds). The timers are usedfor setting the minimum pulse length for example, the signal outputs. Once theinput is activated, the output is set for a specific duration using the Pulse time setting.



Signals

Table 119: TPSGAPC Output signals



Settings

Table 120: TPSGAPC Non group settings

Parameter Values (Range) Unit Step Default DescriptionPulse time 0...300 s 1 0 Minimum pulse time



3.13.2.3 Minimum pulse timer TPMGAPC

Function block

GUID-AB26B298-F7FA-428F-B498-6605DB5B0661 V1 EN


FunctionalityThe Minimum minute pulse timer function TPMGAPC contains two independenttimers. The function has a settable pulse length (in minutes). The timers are usedfor setting the minimum pulse length for example, the signal outputs. Once theinput is activated, the output is set for a specific duration using the Pulse time setting.



Signals

Table 121: TPMGAPC Output signals



Settings

Table 122: TPMGAPC Non group settings

Parameter Values (Range) Unit Step Default DescriptionPulse time 0...300 min 1 0 Minimum pulse time



3.13.3 Pulse timer function block PTGAPC


GUID-2AA275E8-31D4-4CFE-8BDA-A377213BBA89 V1 EN



The pulse timer function block PTGAPC contains eight independent timers. Thefunction has a settable pulse length. Once the input is activated, the output is set fora specific duration using the Pulse delay time setting.

t0 t0+dt t1 t1+dt t2 t2+dt

dt = Pulse delay timeGUID-08F451EE-5110-41D9-95ED-084D7296FA22 V1 EN

Figure 53: Timer operation

3.13.3.3 Signals

Table 123: PTGAPC Input signals

Name Type Default DescriptionIN1 BOOLEAN 0=False Input 1 status

IN2 BOOLEAN 0=False Input 2 status









Table 124: PTGAPC Output signals

Name Type DescriptionQ1 BOOLEAN Output 1 status

Q2 BOOLEAN Output 2 status







3.13.3.4 Settings

Table 125: PTGAPC Non group settings

Parameter Values (Range) Unit Step Default DescriptionPulse delay time 1 0...3600000 ms 10 0 Pulse delay time

Pulse delay time 2 0...3600000 ms 10 0 Pulse delay time







3.13.3.5 Technical data

Table 126: PTGAPC Technical data

Characteristic ValueOperate time accuracy ±1.0% of the set value or ±20 ms



3.13.4 Time-delay-off function block TOFGAPC


GUID-6BFF6180-042F-4526-BB80-D53B2458F376 V1 EN



The time-delay-off function block TOFGAPC can be used, for example, for a drop-off-delayed output related to the input signal. TOFGAPC contains eightindependent timers. There is a settable delay in the timer. Once the input isactivated, the output is set immediately. When the input is cleared, the output stayson until the time set with the Off delay time setting has elapsed.

t0 t1+dt t2 t3 t5+dt

dt = Off delay time

t1 t4 t5

GUID-D45492E6-5FBC-420C-B1BF-B3A1F65ADF96 V1 EN


3.13.4.3 Signals

Table 127: TOFGAPC Input signals












Table 128: TOFGAPC Output signals

Name Type DescriptionQ1 BOOLEAN Output 1 status








3.13.4.4 Settings

Table 129: TOFGAPC Non group settings

Parameter Values (Range) Unit Step Default DescriptionOff delay time 1 0...3600000 ms 10 0 Off delay time

Off delay time 2 0...3600000 ms 10 0 Off delay time








Table 130: TOFGAPC Technical data




3.13.5 Time-delay-on function block TONGAPC


GUID-B694FC27-E6AB-40FF-B1C7-A7EB608D6866 V1 EN



The time-delay-on function block TONGAPC can be used, for example, for time-delaying the output related to the input signal. TONGAPC contains eightindependent timers. The timer has a settable time delay. Once the input is activated,the output is set after the time set by the On delay time setting has elapsed.

t0 t0+dt t2 t3 t4+dt

dt = On delay time

t1 t4 t5

GUID-B74EE764-8B2E-4FBE-8CE7-779F6B739A11 V1 EN


3.13.5.3 Signals

Table 131: TONGAPC Input signals

Name Type Default DescriptionIN1 BOOLEAN 0=False Input 1

IN2 BOOLEAN 0=False Input 2







Name Type Default DescriptionIN6 BOOLEAN 0=False Input 6



Table 132: TONGAPC Output signals

Name Type DescriptionQ1 BOOLEAN Output 1

Q2 BOOLEAN Output 2

Q3 BOOLEAN Output 3

Q4 BOOLEAN Output 4

Q5 BOOLEAN Output 5

Q6 BOOLEAN Output 6

Q7 BOOLEAN Output 7

Q8 BOOLEAN Output 8

3.13.5.4 Settings

Table 133: TONGAPC Non group settings

Parameter Values (Range) Unit Step Default DescriptionOn delay time 1 0...3600000 ms 10 0 On delay time

On delay time 2 0...3600000 ms 10 0 On delay time








Table 134: TONGAPC Technical data




3.13.6 Set-reset function block SRGAPC


GUID-93136D07-FDC4-4356-95B5-54D3B2FC9B1C V1 EN



The SRGAPC function block is a simple SR flip-flop with a memory that can beset or that can reset an output from the S# or R# inputs, respectively. SRGAPCcontains eight independent set-reset flip-flop latches where the SET input has thehigher priority over the RESET input. The status of each Q# output is retained inthe nonvolatile memory. The individual reset for each Q# output is available on theLHMI or through tool via communication.

Table 135: Truth table for SRGAPC

S# R# Q#0 0 01)

0 1 0

1 0 1

1 1 1

1) Keep state/no change



3.13.6.3 Signals

Table 136: SRGAPC Input signals

Name Type Default DescriptionS1 BOOLEAN 0=False Set Q1 output when set

R1 BOOLEAN 0=False Resets Q1 output when set

S2 BOOLEAN 0=False Set Q2 output when set














Table 137: SRGAPC Output signals

Name Type DescriptionQ1 BOOLEAN Q1 status

Q2 BOOLEAN Q2 status









3.13.6.4 Settings

Table 138: SRGAPC Non group settings

Parameter Values (Range) Unit Step Default DescriptionReset Q1 0=Cancel

1=Reset 0=Cancel Resets Q1 output when set

Reset Q2 0=Cancel1=Reset

0=Cancel Resets Q2 output when set













3.13.7 Move function block MVGAPC


GUID-C79D9450-8CB2-49AF-B825-B702EA2CD9F5 V1 EN



The move function block MVGAPC is used for user logic bits. Each input state isdirectly copied to the output state. This allows the creating of events fromadvanced logic combinations.



3.13.7.3 Signals

Table 139: MVGAPC Output signals

Name Type DescriptionQ1 BOOLEAN Q1 status








3.13.8 Local/remote control function block CONTROL


GUID-FA386432-3AEF-468D-B25E-D1C5BDA838E3 V2 EN



Local/Remote control is by default realized through the R/L button on the frontpanel. The control via binary input can be enabled by setting the value of the LRcontrol setting to "Binary input".

The actual Local/Remote control state is evaluated by the priority scheme on thefunction block inputs. If more than one input is active, the input with the highestpriority is selected.

The actual state is reflected on the CONTROL function outputs. Only one output isactive at a time.



Table 140: Truth table for CONTROL

Input OutputCTRL_OFF CTRL_LOC CTRL_STA 1) CTRL_REMTRUE any any any OFF = TRUE

FALSE TRUE any any LOCAL = TRUE

FALSE FALSE TRUE any STATION =TRUE

FALSE FALSE FALSE TRUE REMOTE = TRUE

FALSE FALSE FALSE FALSE OFF = TRUE

1) If station authority is not in use, the CTRL_STA input is interpreted as CTRL_REM.

The station authority check based on the IEC 61850 command originator categoryin control command can be enabled by setting the value of the Station authoritysetting to "Station, Remote" (The command originator validation is performed onlyif the LR control setting is set to "Binary input"). The station authority check is notin use by default.

3.13.8.3 Signals

Table 141: CONTROL input signals

Name Type Default DescriptionCTRL_OFF BOOLEAN 0 Control input OFF

CTRL_LOC BOOLEAN 0 Control input Local

CTRL_STA BOOLEAN 0 Control input Station

CTRL_REM BOOLEAN 0 Control input Remote

Table 142: CONTROL output signals

Name Type DescriptionOFF BOOLEAN Control output OFF

LOCAL BOOLEAN Control output Local

STATION BOOLEAN Control output Station

REMOTE BOOLEAN Control output Remote



3.13.8.4 Settings

Table 143: CONTROL settings

Parameter Values (Range) Unit Step Default DescriptionLR control 1 = "LR key"

2 = "Binaryinput"

1 = "LR key" LR controlthrough LRkey or binaryinput

Stationauthority

1 = "Not used"2 = "StationRemote"

1 = "Not used" Controlcommandoriginatorcategoryusage



3.13.8.5 Monitored data

Table 144: CONTROL Monitored data

Parameter Type Values (Range) Unit DescriptionCommandresponse

ENUM 1 = "Select open"2 = "Select close"3 = "Operateopen"4 = "Operateclose"5 = "Direct open"6 = "Direct close"7 = "Cancel"8 = "Positionreached"9 = "Positiontimeout"10 = "Objectstatus only"11 = "Objectdirect"12 = "Objectselect"13 = "RL localallowed"14 = "RL remoteallowed"15 = "RL off"16 = "Function off"17 = "Functionblocked"18 = "Commandprogress"19 = "Selecttimeout"20 = "Missingauthority"21 = "Close notenabled"22 = "Open notenabled"23 = "Internalfault"24 = "Alreadyclose"25 = "Wrongclient"26 = "RL stationallowed"27 = "RL change"

Latest commandresponse

LR state ENUM 1 = "OFF"2 = "Local"3 = "Remote"4 = "Station"

LR statemonitoring forPCM



3.13.9 Generic control points function block SPCGGIO


GUID-B1380341-22B1-4C7E-A57B-39DBBB9D7B92 V1 EN



The generic control points function SPCGGIO contains 16 independent controlpoints. SPCGGIO offers the capability to activate its outputs through a local orremote control. The local control request can be issued through the buttons in thesingle-line diagram or via inputs and the remote control request throughcommunication. The rising edge of the input signal is interpreted as a controlrequest, and the output operation is triggered. When remote control requests areused the control points behaves as persistent.

The Loc Rem restriction setting is used for enabling or disabling the restriction forSPCGGIO to follow the R/L button state. If Loc Rem restriction is "True", as it isby default, the local or remote control operations are accepted according to the R/Lbutton state.

Each of the 16 generic control point outputs has the Operation mode, Pulse lengthand Description setting. If Operation mode is "Toggle", the output state is toggledfor every control request received. If Operation mode is "Pulsed", the output pulseof a preset duration (the Pulse length setting) is generated for every control requestreceived. The Description setting can be used for storing information on the actualuse of the control point in application, for instance.

The BLOCK input can be used for blocking the functionality of the outputs. Theoperation of the BLOCK input depends on the Operation mode setting. If Operationmode is "Toggle", the output state freezes and cannot be changed while the BLOCKinput is active. If Operation mode is "Pulsed", the activation of the BLOCK inputresets the outputs to the "False" state and further control requests are ignored whilethe BLOCK input is active.



3.13.9.3 Signals

Table 145: SPCGGIO Input signals

Name Type Default DescriptionBLOCK BOOLEAN 0=False Block signal for activating the blocking mode

IN1 BOOLEAN 0=False Input of control point 1
















Table 146: SPCGGIO Output signals

Name Type DescriptionO1 BOOLEAN Output 1 status

O2 BOOLEAN Output 2 status

















3.13.9.4 Settings

Table 147: SPCGGIO Non group settings

Parameter Values (Range) Unit Step Default DescriptionLoc Rem restriction 0=False

1=True 1=True Local remote switch restriction

Operation mode 0=Pulsed1=Toggle-1=Off

-1=Off Operation mode for generic control point

Pulse length 10...3600000 ms 10 1000 Pulse length for pulsed operation mode

Description SPCGGIO1Output 1

Generic control point description


































Parameter Values (Range) Unit Step Default DescriptionOperation mode 0=Pulsed

1=Toggle-1=Off











































Parameter Values (Range) Unit Step Default DescriptionOperation mode 0=Pulsed

1=Toggle-1=Off





3.14 Factory settings restoration

In case of configuration data loss or any other file system error that prevents theIED from working properly, the whole file system can be restored to the originalfactory state. All default settings and configuration files stored in the factory arerestored. For further information on restoring factory settings, see the operationmanual.



Section 4 Protection functions

4.1 Three-phase current protection

4.1.1 Three-phase non-directional overcurrent protectionPHxPTOC

4.1.1.1 Identification

Function description IEC 61850identification

IEC 60617identification

ANSI/IEEE C37.2device number

Three-phase non-directionalovercurrent protection - Low stage

PHLPTOC 3I> 51P-1

Three-phase non-directionalovercurrent protection - High stage

PHHPTOC 3I>> 51P-2

Three-phase non-directionalovercurrent protection - Instantaneousstage

PHIPTOC 3I>>> 50P/51P


A070553 V1 EN



The three-phase overcurrent protection PHxPTOC is used as one-phase, two-phaseor three-phase non-directional overcurrent and short-circuit protection.

The function starts when the current exceeds the set limit. The operate timecharacteristics for low stage PHLPTOC and high stage PHHPTOC can be selectedto be either definite time (DT) or inverse definite minimum time (IDMT).Theinstantaneous stage PHIPTOC always operates with the DT characteristic.

1MRS756887 G Section 4Protection functions


In the DT mode, the function operates after a predefined operate time and resetswhen the fault current disappears. The IDMT mode provides current-dependenttimer characteristics.

The function contains a blocking functionality. It is possible to block functionoutputs, timers or the function itself, if desired.

4.1.1.4 Operation principle

The function can be enabled and disabled with the Operation setting. Thecorresponding parameter values are "On" and "Off".

The operation of three-phase non-directional overcurrent protection can bedescribed by using a module diagram. All the modules in the diagram are explainedin the next sections.

A070552 V1 EN

Figure 63: Functional module diagram. I_A, I_B and I_C represent phasecurrents.

Level detectorThe measured phase currents are compared phasewise to the set Start value. If themeasured value exceeds the set Start value, the level detector reports the exceedingof the value to the phase selection logic. If the ENA_MULT input is active, the Startvalue setting is multiplied by the Start value Mult setting.

The IED does not accept the Start value or Start value Mult settingif the product of these settings exceeds the Start value setting range.

The start value multiplication is normally done when the inrush detection function(INRPHAR) is connected to the ENA_MULT input.

Section 4 1MRS756887 GProtection functions


A070554 V1 EN

Figure 64: Start value behavior with ENA_MULT input activated

Phase selection logicIf the fault criteria are fulfilled in the level detector, the phase selection logicdetects the phase or phases in which the measured current exceeds the setting. Ifthe phase information matches the Num of start phases setting, the phase selectionlogic activates the timer module.

TimerOnce activated, the timer activates the START output. Depending on the value ofthe Operating curve type setting, the time characteristics are according to DT orIDMT. When the operation timer has reached the value of Operate delay time inthe DT mode or the maximum value defined by the inverse time curve, theOPERATE output is activated.

When the user-programmable IDMT curve is selected, the operation timecharacteristics are defined by the parameters Curve parameter A, Curve parameterB, Curve parameter C, Curve parameter D and Curve parameter E.

If a drop-off situation happens, that is, a fault suddenly disappears before theoperate delay is exceeded, the timer reset state is activated. The functionality of thetimer in the reset state depends on the combination of the Operating curve type,Type of reset curve and Reset delay time settings. When the DT characteristic isselected, the reset timer runs until the set Reset delay time value is exceeded. Whenthe IDMT curves are selected, the Type of reset curve setting can be set to"Immediate", "Def time reset" or "Inverse reset". The reset curve type "Immediate"



causes an immediate reset. With the reset curve type "Def time reset", the resettime depends on the Reset delay time setting. With the reset curve type "Inversereset", the reset time depends on the current during the drop-off situation. TheSTART output is deactivated when the reset timer has elapsed.

The "Inverse reset" selection is only supported with ANSI or userprogrammable types of the IDMT operating curves. If anotheroperating curve type is selected, an immediate reset occurs duringthe drop-off situation.

The setting Time multiplier is used for scaling the IDMT operate and reset times.

The setting parameter Minimum operate time defines the minimum desired operatetime for IDMT. The setting is applicable only when the IDMT curves are used.

The Minimum operate time setting should be used with great carebecause the operation time is according to the IDMT curve, butalways at least the value of the Minimum operate time setting. Formore information, see the IDMT curves for overcurrent protectionsection in this manual.

The timer calculates the start duration value START_DUR, which indicates thepercentage ratio of the start situation and the set operating time. The value isavailable in the monitored data view.

Blocking logicThere are three operation modes in the blocking functionality. The operation modesare controlled by the BLOCK input and the global setting "Configuration/System/Blocking mode" which selects the blocking mode. The BLOCK input can becontrolled by a binary input, a horizontal communication input or an internal signalof the IED program. The influence of the BLOCK signal activation is preselectedwith the global setting Blocking mode.

The Blocking mode setting has three blocking methods. In the "Freeze timers"mode, the operation timer is frozen to the prevailing value. In the "Block all"mode, the whole function is blocked and the timers are reset. In the "BlockOPERATE output" mode, the function operates normally but the OPERATE outputis not activated.

4.1.1.5 Measurement modes

The function operates on four alternative measurement modes: "RMS", "DFT","Peak-to-Peak" and "P-to-P + backup". The measurement mode is selected with thesetting Measurement mode.



Table 148: Measurement modes supported by PHxPTOC stages

Measurementmode

Supported measurement modesPHLPTOC PHHPTOC PHIPTOC

RMS x x

DFT x x

Peak-to-Peak x x

P-to-P + backup x

For a detailed description of the measurement modes, see theMeasurement modes section in this manual.

4.1.1.6 Timer characteristics

PHxPTOC supports both DT and IDMT characteristics. The user can select thetimer characteristics with the Operating curve type and Type of reset curve settings.When the DT characteristic is selected, it is only affected by the Operate delaytime and Reset delay time settings.

The IED provides 16 IDMT characteristics curves, of which seven comply with theIEEE C37.112 and six with the IEC 60255-3 standard. Two curves follow thespecial characteristics of ABB praxis and are referred to as RI and RD. In additionto this, a user programmable curve can be used if none of the standard curves areapplicable. The user can choose the DT characteristic by selecting the Operatingcurve type values "ANSI Def. Time" or "IEC Def. Time". The functionality isidentical in both cases.

The following characteristics, which comply with the list in the IEC 61850-7-4specification, indicate the characteristics supported by different stages:

Table 149: Timer characteristics supported by different stages

Operating curve type Supported byPHLPTOC PHHPTOC

(1) ANSI Extremely Inverse x x

(2) ANSI Very Inverse x

(3) ANSI Normal Inverse x x

(4) ANSI Moderately Inverse x

(5) ANSI Definite Time x x

(6) Long Time ExtremelyInverse

x

(7) Long Time Very Inverse x

(8) Long Time Inverse x

(9) IEC Normal Inverse x x

(10) IEC Very Inverse x x




Operating curve type Supported byPHLPTOC PHHPTOC

(11) IEC Inverse x

(12) IEC Extremely Inverse x x

(13) IEC Short Time Inverse x

(14) IEC Long Time Inverse x

(15) IEC Definite Time x x

(17) User programmable x x

(18) RI type x

(19) RD type x

PHIPTOC supports only definite time characteristic.

For a detailed description of timers, see the General function blockfeatures section in this manual.

Table 150: Reset time characteristics supported by different stages

Reset curve type Supported by PHLPTOC PHHPTOC Note

(1) Immediate x x Available for alloperate time curves

(2) Def time reset x x Available for alloperate time curves

(3) Inverse reset x x Available only for ANSIand userprogrammable curves

The Type of reset curve setting does not apply to PHIPTOC orwhen the DT operation is selected. The reset is purely defined bythe Reset delay time setting.

4.1.1.7 Application

PHxPTOC is used in several applications in the power system. The applicationsinclude but are not limited to:



• Selective overcurrent and short-circuit protection of feeders in distribution andsubtransmission systems

• Backup overcurrent and short-circuit protection of power transformers andgenerators

• Overcurrent and short-circuit protection of various devices connected to thepower system, for example shunt capacitor banks, shunt reactors and motors

• General backup protection

PHxPTOC is used for single-phase, two-phase and three-phase non-directionalovercurrent and short-circuit protection. Typically, overcurrent protection is usedfor clearing two and three-phase short circuits. Therefore, the user can choose howmany phases, at minimum, must have currents above the start level for the functionto operate. When the number of start-phase settings is set to "1 out of 3", theoperation of PHxPTOC is enabled with the presence of high current in one-phase.

When the setting is "2 out of 3" or "3 out of 3", single-phase faultsare not detected. The setting "3 out of 3" requires the fault to bepresent in all three phases.

Many applications require several steps using different current start levels and timedelays. PHxPTOC consists of three protection stages.

• Low PHLPTOC• High PHHPTOC• Instantaneous PHIPTOC

PHLPTOC is used for overcurrent protection. The function contains several typesof time-delay characteristics. PHHPTOC and PHIPTOC are used for fast clearanceof very high overcurrent situations.

Transformer overcurrent protectionThe purpose of transformer overcurrent protection is to operate as main protection,when differential protection is not used. It can also be used as coarse back-upprotection for differential protection in faults inside the zone of protection, that is,faults occurring in incoming or outgoing feeders, in the region of transformerterminals and tank cover. This means that the magnitude range of the fault currentcan be very wide. The range varies from 6xIn to several hundred times In,depending on the impedance of the transformer and the source impedance of thefeeding network. From this point of view, it is clear that the operation must be bothvery fast and selective, which is usually achieved by using coarse current settings.

The purpose is also to protect the transformer from short circuits occurring outsidethe protection zone, that is through-faults. Transformer overcurrent protection alsoprovides protection for the LV-side busbars. In this case the magnitude of the faultcurrent is typically lower than 12xIn depending on the fault location andtransformer impedance. Consequently, the protection must operate as fast as



possible taking into account the selectivity requirements, switching-in currents, andthe thermal and mechanical withstand of the transformer and outgoing feeders.

Traditionally, overcurrent protection of the transformer has been arranged asshown in Figure 65. The low-set stage PHLPTOC operates time-selectively both intransformer and LV-side busbar faults. The high-set stage PHHPTOC operatesinstantaneously making use of current selectivity only in transformer HV-sidefaults. If there is a possibility, that the fault current can also be fed from the LV-side up to the HV-side, the transformer must also be equipped with LV-sideovercurrent protection. Inrush current detectors are used in start-up situations tomultiply the current start value setting in each particular IED where the inrushcurrent can occur. The overcurrent and contact based circuit breaker failureprotection CCBRBRF is used to confirm the protection scheme in case of circuitbreaker malfunction.

A070978 V1 EN

Figure 65: Example of traditional time selective transformer overcurrentprotection

The operating times of the main and backup overcurrent protection of the abovescheme become quite long, this applies especially in the busbar faults and also inthe transformer LV-terminal faults. In order to improve the performance of theabove scheme, a multiple-stage overcurrent protection with reverse blocking isproposed. Figure 66 shows this arrangement.

Transformer and busbar overcurrent protection with reverse blockingprincipleBy implementing a full set of overcurrent protection stages and blocking channelsbetween the protection stages of the incoming feeders, bus-tie and outgoingfeeders, it is possible to speed up the operation of overcurrent protection in the



busbar and transformer LV-side faults without impairing the selectivity. Also, thesecurity degree of busbar protection is increased, because there is now a dedicated,selective and fast busbar protection functionality which is based on the blockableovercurrent protection principle. The additional time selective stages on thetransformer HV and LV-sides provide increased security degree of backupprotection for the transformer, busbar and also for the outgoing feeders.

Depending on the overcurrent stage in question, the selectivity of the scheme inFigure 66 is based on the operating current, operating time or blockings betweensuccessive overcurrent stages. With blocking channels, the operating time of theprotection can be drastically shortened if compared to the simple time selectiveprotection. In addition to the busbar protection, this blocking principle is applicablefor the protection of transformer LV terminals and short lines. The functionalityand performance of the proposed overcurrent protections can be summarized asseen in the table.

Table 151: Proposed functionality of numerical transformer and busbar overcurrent protection.DT = definite time, IDMT = inverse definite minimum time

O/C-stage Operating char. Selectivity mode Operation speed SensitivityHV/3I> DT/IDMT time selective low very high

HV/3I>> DT blockable/timeselective

high/low high

HV/3I>>> DT current selective very high low

LV/3I> DT/IDMT time selective low very high

LV/3I>> DT time selective low high

LV/3I>>> DT blockable high high

In case the bus-tie breaker is open, the operating time of the blockable overcurrentprotection is approximately 100 ms (relaying time). When the bus-tie breaker isclosed, that is, the fault current flows to the faulted section of the busbar from twodirections, the operation time becomes as follows: first the bus-tie relay unit tripsthe tie breaker in the above 100 ms, which reduces the fault current to a half. Afterthis the incoming feeder relay unit of the faulted bus section trips the breaker inapproximately 250 ms (relaying time), which becomes the total fault clearing timein this case.



A070980 V2 EN

Figure 66: Numerical overcurrent protection functionality for a typical sub-transmission/distribution substation (feeder protection not shown).Blocking output = digital output signal from the start of a protectionstage, Blocking in = digital input signal to block the operation of aprotection stage

The operating times of the time selective stages are very short, because the gradingmargins between successive protection stages can be kept short. This is mainly dueto the advanced measuring principle allowing a certain degree of CT saturation,good operating accuracy and short retardation times of the numerical units. So, forexample, a grading margin of 150 ms in the DT mode of operation can be used,provided that the circuit breaker interrupting time is shorter than 60 ms.

The sensitivity and speed of the current-selective stages become as good aspossible due to the fact that the transient overreach is practically zero. Also, theeffects of switching inrush currents on the setting values can be reduced by usingthe IED logic, which recognizes the transformer energizing inrush current andblocks the operation or multiplies the current start value setting of the selectedovercurrent stage with a predefined multiplier setting.

Finally, a dependable trip of the overcurrent protection is secured by both a properselection of the settings and an adequate ability of the measuring transformers toreproduce the fault current. This is important in order to maintain selectivity andalso for the protection to operate without additional time delays. For additionalinformation about available measuring modes and current transformerrequirements, see the Measurement modes chapter in this manual.

Radial outgoing feeder overcurrent protectionThe basic requirements for feeder overcurrent protection are adequate sensitivityand operation speed taking into account the minimum and maximum fault current



levels along the protected line, selectivity requirements, inrush currents and thethermal and mechanical withstand of the lines to be protected.

In many cases the above requirements can be best fulfilled by using multiple-stageovercurrent units. Figure 67 shows an example of this. A brief coordination studyhas been carried out between the incoming and outgoing feeders.

The protection scheme is implemented with three-stage numerical overcurrentprotection, where the low-set stage PHLPTOC operates in IDMT-mode and thetwo higher stages PHHPTOC and PHIPTOC in DT-mode. Also the thermalwithstand of the line types along the feeder and maximum expected inrush currentsof the feeders are shown. Faults occurring near the station where the fault currentlevels are the highest are cleared rapidly by the instantaneous stage in order tominimize the effects of severe short circuit faults. The influence of the inrushcurrent is taken into consideration by connecting the inrush current detector to thestart value multiplying input of the instantaneous stage. By this way the start valueis multiplied with a predefined setting during the inrush situation and nuisancetripping can be avoided.



A070982 V1 EN

Figure 67: Functionality of numerical multiple-stage overcurrent protection

The coordination plan is an effective tool to study the operation of time selectiveoperation characteristics. All the points mentioned earlier, required to define theovercurrent protection parameters, can be expressed simultaneously in acoordination plan. In Figure 68, the coordination plan shows an example ofoperation characteristics in the LV-side incoming feeder and radial outgoing feeder.



A070984 V2 EN

Figure 68: Example coordination of numerical multiple-stage overcurrent protection

4.1.1.8 Signals

Table 152: PHLPTOC Input signals

Name Type Default DescriptionI_A SIGNAL 0 Phase A current

I_B SIGNAL 0 Phase B current

I_C SIGNAL 0 Phase C current

BLOCK BOOLEAN 0=False Block signal for activating the blocking mode

ENA_MULT BOOLEAN 0=False Enable signal for current multiplier

Table 153: PHHPTOC Input signals








Table 154: PHIPTOC Input signals






Table 155: PHLPTOC Output signals

Name Type DescriptionOPERATE BOOLEAN Operate

START BOOLEAN Start

Table 156: PHHPTOC Output signals


START BOOLEAN Start

Table 157: PHIPTOC Output signals


START BOOLEAN Start

4.1.1.9 Settings

Table 158: PHLPTOC Group settings

Parameter Values (Range) Unit Step Default DescriptionStart value 0.05...5.00 xIn 0.01 0.05 Start value

Start value Mult 0.8...10.0 0.1 1.0 Multiplier for scaling the start value

Time multiplier 0.05...15.00 0.01 1.00 Time multiplier in IEC/ANSI IDMT curves




Parameter Values (Range) Unit Step Default DescriptionOperate delay time 40...200000 ms 10 40 Operate delay time

Operating curve type 1=ANSI Ext. inv.2=ANSI Very inv.3=ANSI Norm. inv.4=ANSI Mod. inv.5=ANSI Def. Time6=L.T.E. inv.7=L.T.V. inv.8=L.T. inv.9=IEC Norm. inv.10=IEC Very inv.11=IEC inv.12=IEC Ext. inv.13=IEC S.T. inv.14=IEC L.T. inv.15=IEC Def. Time17=Programmable18=RI type19=RD type

15=IEC Def. Time Selection of time delay curve type

Type of reset curve 1=Immediate2=Def time reset3=Inverse reset

1=Immediate Selection of reset curve type

Table 159: PHLPTOC Non group settings



Num of start phases 1=1 out of 32=2 out of 33=3 out of 3

1=1 out of 3 Number of phases required for operateactivation

Minimum operate time 20...60000 ms 1 20 Minimum operate time for IDMT curves

Reset delay time 0...60000 ms 1 20 Reset delay time

Measurement mode 1=RMS2=DFT3=Peak-to-Peak

2=DFT Selects used measurement mode

Curve parameter A 0.0086...120.0000 28.2000 Parameter A for customer programmablecurve

Curve parameter B 0.0000...0.7120 0.1217 Parameter B for customer programmablecurve

Curve parameter C 0.02...2.00 2.00 Parameter C for customerprogrammable curve

Curve parameter D 0.46...30.00 29.10 Parameter D for customerprogrammable curve

Curve parameter E 0.0...1.0 1.0 Parameter E for customer programmablecurve



Table 160: PHHPTOC Group settings




Operate delay time 40...200000 ms 10 40 Operate delay time

Operating curve type 1=ANSI Ext. inv.3=ANSI Norm. inv.5=ANSI Def. Time9=IEC Norm. inv.10=IEC Very inv.12=IEC Ext. inv.15=IEC Def. Time17=Programmable




Table 161: PHHPTOC Non group settings














Table 162: PHIPTOC Group settings






Table 163: PHIPTOC Non group settings







Table 164: PHLPTOC Monitored data

Name Type Values (Range) Unit DescriptionSTART_DUR FLOAT32 0.00...100.00 % Ratio of start time /

operate time

PHLPTOC Enum 1=on2=blocked3=test4=test/blocked5=off

Status

Table 165: PHHPTOC Monitored data


operate time

PHHPTOC Enum 1=on2=blocked3=test4=test/blocked5=off

Status

Table 166: PHIPTOC Monitored data


operate time

PHIPTOC Enum 1=on2=blocked3=test4=test/blocked5=off

Status




Table 167: PHxPTOC Technical data

Characteristic ValueOperation accuracy Depending on the frequency of the current

measured: fn ±2 Hz

PHLPTOC ±1.5% of the set value or ±0.002 x In

PHHPTOCandPHIPTOC

±1.5% of set value or ±0.002 x In(at currents in the range of 0.1…10 x In)±5.0% of the set value(at currents in the range of 10…40 x In)

Start time 1)2) Minimum Typical Maximum

PHIPTOC:IFault = 2 x set StartvalueIFault = 10 x set Startvalue

16 ms 11 ms

19 ms 12 ms

23 ms 14 ms

PHHPTOC andPHLPTOC:IFault = 2 x set Startvalue

22 ms

24 ms

25 ms

Reset time < 40 ms

Reset ratio Typical 0.96

Retardation time < 30 ms

Operate time accuracy in definite time mode ±1.0% of the set value or ±20 ms

Operate time accuracy in inverse time mode ±5.0% of the theoretical value or ±20 ms 3)

Suppression of harmonics RMS: No suppressionDFT: -50 dB at f = n x fn, where n = 2, 3, 4, 5,…Peak-to-Peak: No suppressionP-to-P+backup: No suppression

1) Measurement mode = default (depends on stage), current before fault = 0.0 x In, fn = 50 Hz, faultcurrent in one phase with nominal frequency injected from random phase angle, results based onstatistical distribution of 1000 measurements

2) Includes the delay of the signal output contact3) Maximum Start value = 2.5 x In, Start value multiples in range of 1.5 to 20

4.1.1.12 Technical revision history

Table 168: PHIPTOC Technical revision history

Technical revision ChangeB Minimum and default values changed to 40 ms

for the Operate delay time setting.

C Minimum and default values changed to 20 msfor the Operate delay time setting.Minimum value changed to 1.00 x In for the Startvalue setting.



Table 169: PHHPTOC Technical revision history

Technical revision ChangeC Measurement mode "P-to-P + backup" replaced

with "Peak-to-Peak"

D Step value changed from 0.05 to 0.01 for theTime multiplier setting.

Table 170: PHLPTOC Technical revision history


for the Operate delay time setting

C Step value changed from 0.05 to 0.01 for theTime multiplier setting.

4.1.2 Three-phase directional overcurrent protection DPHxPDOC





Three-phase directional overcurrentprotection - Low stage

DPHLPDOC 3I> -> 67-1

Three-phase directional overcurrentprotection - High stage

DPHHPDOC 3I>> -> 67-2


GUID-9EB77066-518A-4CCC-B973-7EEE31FAE4F1 V3 EN



The three-phase overcurrent protection DPHxPDOC is used as one-phase, two-phase or three-phase directional overcurrent and short-circuit protection for feeders.

DPHxPDOC starts up when the value of the current exceeds the set limit anddirectional criterion is fulfilled. The operate time characteristics for low stage



DPHLPDOC and high stage DPHHPDOC can be selected to be either definite time(DT) or inverse definite minimum time (IDMT).





The operation of directional overcurrent protection can be described using amodule diagram. All the modules in the diagram are explained in the next sections.

GUID-C5892F3E-09D9-462E-A963-023EFC18DDE7 V3 EN

Figure 70: Functional module diagram

Directional calculationThe directional calculation compares the current phasors to the polarizing phasor.A suitable polarization quantity can be selected from the different polarizationquantities, which are the positive sequence voltage, negative sequence voltage, self-polarizing (faulted) voltage and cross-polarizing voltages (healthy voltages). Thepolarizing method is defined with the Pol quantity setting.



Table 171: Polarizing quantities

Polarizing quantity DescriptionPos. seq. volt Positive sequence voltage

Neg. seq. volt Negative sequence voltage

Self pol Self polarization

Cross pol Cross polarization

The directional operation can be selected with the Directional mode setting. Theuser can select either "Non-directional", "Forward" or "Reverse" operation. Bysetting the value of Allow Non Dir to "True", the non-directional operation isallowed when the directional information is invalid.

The Characteristic angle setting is used to turn the directional characteristic. Thevalue of Characteristic angle should be chosen in such a way that all the faults inthe operating direction are seen in the operating zone and all the faults in theopposite direction are seen in the non-operating zone. The value of Characteristicangle depends on the network configuration.

Reliable operation requires both the operating and polarizing quantities to exceedcertain minimum amplitude levels. The minimum amplitude level for the operatingquantity (current) is set with the Min operate current setting. The minimumamplitude level for the polarizing quantity (voltage) is set with the Min operatevoltage setting. If the amplitude level of the operating quantity or polarizingquantity is below the set level, the direction information of the corresponding phaseis set to "Unknown".

The polarizing quantity validity can remain valid even if the amplitude of thepolarizing quantity falls below the value of the Min operate voltage setting. In thiscase, the directional information is provided by a special memory function for atime defined with the Voltage Mem time setting.

DPHxPDOC is provided with a memory function to secure a reliable and correctdirectional IED operation in case of a close short circuit or an earth faultcharacterized by an extremely low voltage. At sudden loss of the polarizationquantity, the angle difference is calculated on the basis of a fictive voltage. Thefictive voltage is calculated using the positive phase sequence voltage measuredbefore the fault occurred, assuming that the voltage is not affected by the fault. Thememory function enables the function to operate up to a maximum of three secondsafter a total loss of voltage. This time can be set with the Voltage Mem time setting.The voltage memory cannot be used for the "Negative sequence voltage"polarization because it is not possible to substitute the positive sequence voltage fornegative sequence voltage without knowing the network unsymmetry level. This isthe reason why the fictive voltage angle and corresponding direction informationare frozen immediately for this polarization mode when the need for a voltagememory arises and these are kept frozen until the time set with Voltage Mem timeelapses.



The value for the Min operate voltage setting should be carefullyselected since the accuracy in low signal levels is strongly affectedby the measuring device accuracy.

When the voltage falls below Min operate voltage at a close fault, the fictivevoltage is used to determine the phase angle. The measured voltage is applied againas soon as the voltage rises above Min operate voltage and hysteresis. The fictivevoltage is also discarded if the measured voltage stays below Min operate voltageand hysteresis for longer than Voltage Mem time or if the fault current disappearswhile the fictive voltage is in use. When the voltage is below Min operate voltageand hysteresis and the fictive voltage is unusable, the fault direction cannot bedetermined. The fictive voltage can be unusable for two reasons:

• The fictive voltage is discarded after Voltage Mem time• The phase angle cannot be reliably measured before the fault situation.

DPHxPDOC can be forced to the non-directional operation with the NON_DIRinput. When the NON_DIR input is active, DPHxPDOC operates as a non-directional overcurrent protection, regardless of the Directional mode setting.

GUID-718D61B4-DAD0-4F43-8108-86F7B44E7E2D V1 EN

Figure 71: Operating zones at minimum magnitude levels



Level detectorThe measured phase currents are compared phasewise to the set Start value. If themeasured value exceeds the set Start value, the level detector reports the exceedingof the value to the phase selection logic. If the ENA_MULT input is active, the Startvalue setting is multiplied by the Start value Mult setting.



A070554 V1 EN

Figure 72: Start value behavior with ENA_MULT input activated

Phase selection logicIf the fault criteria are fulfilled in the level detector and the directional calculation,the phase selection logic detects the phase or phases in which the measured currentexceeds the setting. If the phase information matches the Num of start phasessetting, the phase selection logic activates the timer module.

TimerOnce activated, the timer activates the START output. Depending on the value ofthe Operating curve type setting, the time characteristics are according to DT orIDMT. When the operation timer has reached the value of Operate delay time in



the DT mode or the maximum value defined by the inverse time curve, theOPERATE output is activated.


If a drop-off situation happens, that is, a fault suddenly disappears before theoperate delay is exceeded, the timer reset state is activated. The functionality of thetimer in the reset state depends on the combination of the Operating curve type,Type of reset curve and Reset delay time settings. When the DT characteristic isselected, the reset timer runs until the set Reset delay time value is exceeded. Whenthe IDMT curves are selected, the Type of reset curve setting can be set to"Immediate", "Def time reset" or "Inverse reset". The reset curve type "Immediate"causes an immediate reset. With the reset curve type "Def time reset", the resettime depends on the Reset delay time setting. With the reset curve type "Inversereset", the reset time depends on the current during the drop-off situation. TheSTART output is deactivated when the reset timer has elapsed.











The function operates on three alternative measurement modes: “RMS”, “DFT”and “Peak-to-Peak” . The measurement mode is selected with the Measurementmode setting.

Table 172: Measurement modes supported by DPHxPDOC stages

Measurement mode Supported measurement modesDPHLPDOC DPHHPDOC

RMS x x

DFT x x

Peak-to-Peak x x

4.1.2.6 Directional overcurrent characteristics

The forward and reverse sectors are defined separately. The forward operation areais limited with the Min forward angle and Max forward angle settings. The reverseoperation area is limited with the Min reverse angle and Max reverse angle settings.

The sector limits are always given as positive degree values.

In the forward operation area, the Max forward angle setting gives thecounterclockwise sector and the Min forward angle setting gives the correspondingclockwise sector, measured from the Characteristic angle setting.

In the backward operation area, the Max reverse angle setting gives thecounterclockwise sector and the Min reverse angle setting gives the correspondingclockwise sector, a measurement from the Characteristic angle setting that hasbeen rotated 180 degrees.

Relay characteristic angle (RCA) is set positive if the operating current lags thepolarizing quantity and negative if the operating current leads the polarizing quantity.



GUID-CD0B7D5A-1F1A-47E6-AF2A-F6F898645640 V2 EN

Figure 73: Configurable operating sectors

Table 173: Momentary per phase direction value for monitored data view

Criterion for per phase direction information The value for DIR_A/_B/_CThe ANGLE_X is not in any of the definedsectors, or the direction cannot be defined duetoo low amplitude

0 = unknown

The ANGLE_X is in the forward sector 1 = forward

The ANGLE_X is in the reverse sector 2 = backward

(The ANGLE_X is in both forward and reversesectors, that is, when the sectors are overlapping)

3 = both

Table 174: Momentary phase combined direction value for monitored data view

Criterion for phase combined direction information The value for DIRECTIONThe direction information (DIR_X) for all phasesis unknown

0 = unknown

The direction information (DIR_X) for at least onephase is forward, none being in reverse

1 = forward

The direction information (DIR_X) for at least onephase is reverse, none being in forward

2 = backward

The direction information (DIR_X) for somephase is forward and for some phase is reverse

3 = both



FAULT_DIR gives the detected direction of the fault during fault situations, that is,when the START output is active.

Self-polarizing as polarizing methodTable 175: Equations for calculating angle difference for self-polarizing method

Faultedphases

Used faultcurrent

Usedpolarizingvoltage

Angle difference

A IA UA ANGLE A U IA A RCA_ ( ) - ( ) - = ϕ ϕ ϕ

GUID-60308BBA-07F8-4FB4-A9E8-3850325E368C V2 EN

B IB UB ANGLE B U IB B RCA_ ( ) - ( ) - = ϕ ϕ ϕ

GUID-9AF57A77-F9C6-46B7-B056-AC7542EBF449 V2 EN

C IC UC ANGLE C U IC C RCA_ ( ) - ( ) - = ϕ ϕ ϕ

GUID-51FEBD95-672C-440F-A678-DD01ABB2D018 V2 EN

A - B IA - IB UAB ANGLE A U I IAB A B RCA_ ( ) - ( - ) - = ϕ ϕ ϕ

GUID-7DA1116D-86C0-4D7F-AA19-DCF32C530C4C V2 EN

B - C IB - IC UBC ANGLE B U I IBC B C RCA_ ( ) - ( - ) - = ϕ ϕ ϕ

GUID-3E9788CA-D2FC-4FC4-8F9E-1466F3775826 V2 EN

C - A IC - IA UCA ANGLE C U I ICA C A RCA_ ( ) - ( - ) - = ϕ ϕ ϕ

GUID-EFD80F78-4B26-46B6-A5A6-CCA6B7E20C6E V2 EN

In an example case of the phasors in a single-phase earth fault where the faultedphase is phase A, the angle difference between the polarizing quantity UA andoperating quantity IA is marked as φ. In the self-polarization method, there is noneed to rotate the polarizing quantity.

GUID-C648173C-D8BB-4F37-8634-5D4DC7D366FF V1 EN

Figure 74: Single-phase earth fault, phase A



In an example case of a two-phase short-circuit failure where the fault is betweenphases B and C, the angle difference is measured between the polarizing quantityUBC and operating quantity IB - IC in the self-polarizing method.

GUID-65CFEC0E-0367-44FB-A116-057DD29FEB79 V1 EN

Figure 75: Two-phase short circuit, short circuit is between phases B and C

Cross-polarizing as polarizing quantityTable 176: Equations for calculating angle difference for cross-polarizing method

Faultedphases

Usedfaultcurrent


Angle difference

A IA UBCANGLE A U I

BC A RCA

o_ ( ) - ( ) - = +ϕ ϕ ϕ 90

GUID-4F0D1491-3679-4B1F-99F7-3704BC15EF9D V3 EN

B IB UCAANGLE B U I

CA B RCA

o_ ( ) - ( ) - = +ϕ ϕ ϕ 90

GUID-F5252292-E132-41A7-9F6D-C2A3958EE6AD V3 EN

C IC UABANGLE C U I

AB C RCA

o_ ( ) - ( ) - = +ϕ ϕ ϕ 90

GUID-84D97257-BAEC-4264-9D93-EC2DF853EAE1 V3 EN

A - B IA - IB UBC -UCA

ANGLE A U U I IBC CA A B RCA

o_ ( - ) - ( - ) - = +ϕ ϕ ϕ 90

GUID-AFB15C3F-B9BB-47A2-80E9-796AA1165409 V2 EN

B - C IB - IC UCA -UAB

ANGLE B U U I ICA AB B C RCA

o_ ( - ) - ( - ) - = +ϕ ϕ ϕ 90

GUID-C698D9CA-9139-40F2-9097-007B6B14D053 V2 EN

C - A IC - IA UAB -UBC

ANGLE C U U I IAB BC C A RCA

o_ ( - ) - ( - ) - = +ϕ ϕ ϕ 90

GUID-838ECE7D-8B1C-466F-8166-E8FE16D28AAD V2 EN

The angle difference between the polarizing quantity UBC and operating quantityIA is marked as φ in an example of the phasors in a single-phase earth fault where



the faulted phase is phase A. The polarizing quantity is rotated with 90 degrees.The characteristic angle is assumed to be ~ 0 degrees.

GUID-6C7D1317-89C4-44BE-A1EB-69BC75863474 V1 EN

Figure 76: Single-phase earth fault, phase A

In an example of the phasors in a two-phase short-circuit failure where the fault isbetween the phases B and C, the angle difference is measured between thepolarizing quantity UAB and operating quantity IB - IC marked as φ.



GUID-C2EC2EF1-8A84-4A32-818C-6D7620EA9969 V1 EN

Figure 77: Two-phase short circuit, short circuit is between phases B and C

The equations are valid when network rotating direction is counter-clockwise, that is, ABC. If the network rotating direction isreversed, 180 degrees is added to the calculated angle difference.This is done automatically with a system parameter Phase rotation.

Negative sequence voltage as polarizing quantityWhen the negative voltage is used as the polarizing quantity, the angle differencebetween the operating and polarizing quantity is calculated with the same formulafor all fault types:

ANGLE X U I RCA_ ( ) ( )= − − −ϕ ϕ ϕ2 2

GUID-470263DD-C1D7-4E59-B011-24D8D35BD52A V3 EN (Equation 1)



This means that the actuating polarizing quantity is -U2.

UA

UBUC UBC

UABUCA

IA

IBIC U2

I2

UA

UBUC

IA

IBIC

U2

I2

A BGUID-027DD4B9-5844-4C46-BA9C-54784F2300D3 V2 EN

Figure 78: Phasors in a single-phase earth fault, phases A-N, and two-phaseshort circuit, phases B and C, when the actuating polarizingquantity is the negative-sequence voltage -U2

Positive sequence voltage as polarizing quantityTable 177: Equations for calculating angle difference for positive-sequence quantity polarizing

method

Faultedphases

Used faultcurrent


Angle difference

A IA U1 ANGLE A U IA RCA_ ( ) ( )= − −ϕ ϕ ϕ1

GUID-4C933201-2290-4AA3-97A3-670A40CC4114 V4 EN

B IB U1ANGLE B U I

B RCA_ ( ) ( )= − − −ϕ ϕ ϕ1 120o

GUID-648D061C-6F5F-4372-B120-0F02B42E9809 V4 EN

C IC U1ANGLE C U I

C RCA_ ( ) ( )= − − +ϕ ϕ ϕ1 120o

GUID-355EF014-D8D0-467E-A952-1D1602244C9F V4 EN

A - B IA - IB U1ANGLE A U I I

A B RCA_ ( ) ( )= − − − +ϕ ϕ ϕ1 30o

GUID-B07C3B0A-358E-480F-A059-CC5F3E6839B1 V3 EN

B - C IB - IC U1ANGLE B U I I

B C RCA_ ( ) ( )= − − − −ϕ ϕ ϕ1 90o

GUID-4597F122-99A6-46F6-A38C-81232C985BC9 V3 EN

C - A IC - IA U1ANGLE C U I I

C A RCA_ ( ) ( )= − − − +ϕ ϕ ϕ1 150o

GUID-9892503C-2233-4BC5-8C54-BCF005E20A08 V3 EN



UA

UBUC

IA

IBIC

UA

UBUC

IA

IBIC

A B

-IC

IB - Ic

-90°

U1

U1

GUID-1937EA60-4285-44A7-8A7D-52D7B66FC5A6 V3 EN

Figure 79: Phasors in a single-phase earth fault, phase A to ground, and a two-phase short circuit, phases B-C, are short-circuited when thepolarizing quantity is the positive-sequence voltage U1

Network rotation directionTypically, the network rotating direction is counter-clockwise and defined as"ABC". If the network rotating direction is reversed, meaning clockwise, that is,"ACB", the equations for calculating the angle difference needs to be changed. Thenetwork rotating direction is defined with a system parameter Phase rotation. Thechange in the network rotating direction affects the phase-to-phase voltagespolarization method where the calculated angle difference needs to be rotated 180degrees. Also, when the sequence components are used, which are, the positivesequence voltage or negative sequence voltage components, the calculation of thecomponents are affected but the angle difference calculation remains the same.When the phase-to-ground voltages are used as the polarizing method, the networkrotating direction change has no effect on the direction calculation.

The network rotating direction is set in the IED using the parameterin the HMI menu: Configuration/System/Phase rotation. Thedefault parameter value is "ABC".



UBUC

UA

UCUB

UA

NETWORK ROTATION ABC NETWORK ROTATION ACB

UBC

UABUCA

UBC

UCAUAB

IA

IB

IC

IA

IB

IC

GUID-BF32C1D4-ECB5-4E96-A27A-05C637D32C86 V2 EN

Figure 80: Examples of network rotating direction

4.1.2.7 Application

DPHxPDOC is used as short-circuit protection in three-phase distribution or subtransmission networks operating at 50 or 60 Hz.

In radial networks, phase overcurrent IEDs are often sufficient for the short circuitprotection of lines, transformers and other equipment. The current-timecharacteristic should be chosen according to the common practice in the network. Itis recommended to use the same current-time characteristic for all overcurrentIEDs in the network. This includes the overcurrent protection of transformers andother equipment.

The phase overcurrent protection can also be used in closed ring systems as shortcircuit protection. Because the setting of a phase overcurrent protection system inclosed ring networks can be complicated, a large number of fault currentcalculations are needed. There are situations with no possibility to have theselectivity with a protection system based on overcurrent IEDs in a closed ring system.

In some applications, the possibility of obtaining the selectivity can be improvedsignificantly if DPHxPDOC is used. This can also be done in the closed ringnetworks and radial networks with the generation connected to the remote in thesystem thus giving fault current infeed in reverse direction. Directional overcurrentIEDs are also used to have a selective protection scheme, for example in case ofparallel distribution lines or power transformers fed by the same single source. Inring connected supply feeders between substations or feeders with two feedingsources, DPHxPDOC is also used.

Parallel lines or transformersWhen the lines are connected in parallel and if a fault occurs in one of the lines, itis practical to have DPHxPDOC to detect the direction of the fault. Otherwise,



there is a risk that the fault situation in one part of the feeding system can de-energize the whole system connected to the LV side.

GUID-1A2BD0AD-B217-46F4-A6B4-6FC6E6256EB3 V2 EN

Figure 81: Overcurrent protection of parallel lines using directional IEDs

DPHxPDOC can be used for parallel operating transformer applications. In theseapplications, there is a possibility that the fault current can also be fed from the LV-side up to the HV-side. Therefore, the transformer is also equipped with directionalovercurrent protection.

GUID-74662396-1BAD-4AC2-ADB6-F4A8B3341860 V2 EN

Figure 82: Overcurrent protection of parallel operating transformers

Closed ring network topologyThe closed ring network topology is used in applications where electricitydistribution for the consumers is secured during network fault situations. Thepower is fed at least from two directions which means that the current direction canbe varied. The time grading between the network level stages is challengingwithout unnecessary delays in the time settings. In this case, it is practical to usethe directional overcurrent IEDs to achieve a selective protection scheme.Directional overcurrent functions can be used in closed ring applications. Thearrows define the operating direction of the directional functionality. The double



arrows define the non-directional functionality where faults can be detected in bothdirections.

GUID-276A9D62-BD74-4335-8F20-EC1731B58889 V1 EN

Figure 83: Closed ring network topology where feeding lines are protectedwith directional overcurrent IEDs

4.1.2.8 Signals

Table 178: DPHLPDOC Input signals




I2 SIGNAL 0 Negative phase sequence current

U_A_AB SIGNAL 0 Phase-to-earth voltage A or phase-to-phasevoltage AB

U_B_BC SIGNAL 0 Phase-to-earth voltage B or phase-to-phasevoltage BC

U_C_CA SIGNAL 0 Phase-to-earth voltage C or phase-to-phasevoltage CA

U1 SIGNAL 0 Positive phase sequence voltage

U2 SIGNAL 0 Negative phase sequence voltage




Name Type Default DescriptionBLOCK BOOLEAN 0=False Block signal for activating the blocking mode

ENA_MULT BOOLEAN 0=False Enabling signal for current multiplier

NON_DIR BOOLEAN 0=False Forces protection to non-directional

Table 179: DPHHPDOC Input signals




I2 SIGNAL 0 Negative phase sequence current

U_A_AB SIGNAL 0 Phase to earth voltage A or phase to phasevoltage AB

U_B_BC SIGNAL 0 Phase to earth voltage B or phase to phasevoltage BC

U_C_CA SIGNAL 0 Phase to earth voltage C or phase to phasevoltage CA




ENA_MULT BOOLEAN 0=False Enabling signal for current multiplier

NON_DIR BOOLEAN 0=False Forces protection to non-directional

Table 180: DPHLPDOC Output signals


START BOOLEAN Start

Table 181: DPHHPDOC Output signals

Name Type DescriptionSTART BOOLEAN Start

OPERATE BOOLEAN Operate



4.1.2.9 Settings

Table 182: DPHLPDOC Group settings









Voltage Mem time 0...3000 ms 1 40 Voltage memory time

Directional mode 1=Non-directional2=Forward3=Reverse

2=Forward Directional mode

Characteristic angle -179...180 deg 1 60 Characteristic angle

Max forward angle 0...90 deg 1 80 Maximum phase angle in forwarddirection

Max reverse angle 0...90 deg 1 80 Maximum phase angle in reversedirection

Min forward angle 0...90 deg 1 80 Minimum phase angle in forward direction

Min reverse angle 0...90 deg 1 80 Minimum phase angle in reverse direction

Pol quantity -2=Pos. seq. volt.1=Self pol4=Neg. seq. volt.5=Cross pol

5=Cross pol Reference quantity used to determinefault direction



Table 183: DPHLPDOC Non group settings














Allow Non Dir 0=False1=True

0=False Allows prot activation as non-dir when dirinfo is invalid

Min operate current 0.01...1.00 xIn 0.01 0.01 Minimum operating current

Min operate voltage 0.01...1.00 xUn 0.01 0.01 Minimum operating voltage

Table 184: DPHHPDOC Group settings











Characteristic angle -179...180 deg 1 60 Characteristic angle




Parameter Values (Range) Unit Step Default DescriptionMax forward angle 0...90 deg 1 80 Maximum phase angle in forward

direction




Voltage Mem time 0...3000 ms 1 40 Voltage memory time

Pol quantity -2=Pos. seq. volt.1=Self pol4=Neg. seq. volt.5=Cross pol

5=Cross pol Reference quantity used to determinefault direction

Table 185: DPHHPDOC Non group settings





















Table 186: DPHLPDOC Monitored data


operate time

FAULT_DIR Enum 0=unknown1=forward2=backward3=both

Detected fault direction

DIRECTION Enum 0=unknown1=forward2=backward3=both

Direction information

DIR_A Enum 0=unknown1=forward2=backward3=both

Direction phase A

DIR_B Enum 0=unknown1=forward2=backward3=both

Direction phase B

DIR_C Enum 0=unknown1=forward2=backward3=both

Direction phase C

ANGLE_A FLOAT32 -180.00...180.00 deg Calculated angledifference, Phase A

ANGLE_B FLOAT32 -180.00...180.00 deg Calculated angledifference, Phase B

ANGLE_C FLOAT32 -180.00...180.00 deg Calculated angledifference, Phase C

DPHLPDOC Enum 1=on2=blocked3=test4=test/blocked5=off

Status

Table 187: DPHHPDOC Monitored data


operate time








Name Type Values (Range) Unit DescriptionDIR_A Enum 0=unknown

1=forward2=backward3=both

Direction phase A

DIR_B Enum 0=unknown1=forward2=backward3=both

Direction phase B

DIR_C Enum 0=unknown1=forward2=backward3=both

Direction phase C

ANGLE_A FLOAT32 -180.00...180.00 deg Calculated angledifference, Phase A

ANGLE_B FLOAT32 -180.00...180.00 deg Calculated angledifference, Phase B

ANGLE_C FLOAT32 -180.00...180.00 deg Calculated angledifference, Phase C

DPHHPDOC Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 188: DPHxPDOC Technical data

Characteristic ValueOperation accuracy Depending on the frequency of the current/

voltage measured: fn ±2 Hz

DPHLPDOC Current:±1.5% of the set value or ±0.002 x InVoltage:±1.5% of the set value or ±0.002 x UnPhase angle: ±2°

DPHHPDOC Current:±1.5% of the set value or ±0.002 x In(at currents in the range of 0.1…10 x In)±5.0% of the set value(at currents in the range of 10…40 x In)Voltage:±1.5% of the set value or ±0.002 x UnPhase angle: ±2°

Start time1)2) Minimum Typical Maximum

IFault = 2.0 x set Startvalue 38 ms 43 ms 46 ms

Reset time < 40 ms






Characteristic ValueOperate time accuracy in definite time mode ±1.0% of the set value or ±20 ms

Operate time accuracy in inverse time mode ±5.0% of the theoretical value or ±20 ms3)

Suppression of harmonics DFT: -50 dB at f = n x fn, where n = 2, 3, 4, 5,…

1) Measurement mode and Pol quantity = default, current before fault = 0.0 x In, voltage before fault =1.0 x Un, fn = 50 Hz, fault current in one phase with nominal frequency injected from random phaseangle, results based on statistical distribution of 1000 measurements



Table 189: DPHLPDOC Technical revision history

Technical revision ChangeB Added a new input NON_DIR


Table 190: DPHHPDOC Technical revision history

Technical revision ChangeB Added a new input NON_DIR


4.1.3 Three-phase thermal protection for feeders, cables anddistribution transformers T1PTTR





Three-phase thermal protection forfeeders, cables and distributiontransformers

T1PTTR 3lth> 49F




A070691 V2 EN



The increased utilization of power systems closer to the thermal limits hasgenerated a need for a thermal overload function also for power lines.

A thermal overload is in some cases not detected by other protection functions, andthe introduction of the thermal overload function T1PTTR allows the protectedcircuit to operate closer to the thermal limits.

An alarm level gives an early warning to allow operators to take action before theline trips. The early warning is based on the three-phase current measuring functionusing a thermal model with first order thermal loss with the settable time constant.If the temperature rise continues the function will operate based on the thermalmodel of the line.

Re-energizing of the line after the thermal overload operation can be inhibitedduring the time the cooling of the line is in progress. The cooling of the line isestimated by the thermal model.



The operation of the three-phase thermal protection for feeders, cables anddistribution transformers can be described using a module diagram. All themodules in the diagram are explained in the next sections.



Temperatureestimator

ThermalcounterENA_MULT

ALARMBLK_CLOSE

OPERATE

BLK_OPR

STARTMaxcurrentselector

I_AI_BI_C

AMB_TEMPA070747 V3 EN


Max current selectorThe max current selector of the function continuously checks the highest measuredTRMS phase current value. The selector reports the highest value to thetemperature estimator.

Temperature estimatorThe final temperature rise is calculated from the highest of the three-phase currentsaccording to the expression:

Θ final

ref

ref

I

IT=

⋅

2

A070780 V2 EN (Equation 2)

I the largest phase current

Iref set Current reference

Tref set Temperature rise

The ambient temperature is added to the calculated final temperature riseestimation, and the ambient temperature value used in the calculation is alsoavailable in the monitored data as TEMP_AMB in degrees. If the final temperatureestimation is larger than the set Maximum temperature, the START output is activated.

Current reference and Temperature rise setting values are used in the finaltemperature estimation together with the ambient temperature. It is suggested to setthese values to the maximum steady state current allowed for the line or cableunder emergency operation for a few hours per years. Current values with thecorresponding conductor temperatures are given in cable manuals. These values aregiven for conditions such as ground temperatures, ambient air temperature, the wayof cable laying and ground thermal resistivity.

Thermal counterThe actual temperature at the actual execution cycle is calculated as:



Θ Θ Θ Θ

∆

n n final n

t

e= + −( ) ⋅ −

− −

−

1 1 1 τ


Θn calculated present temperature

Θn-1 calculated temperature at previous time step

Θfinal calculated final temperature with actual current

Δt time step between calculation of actual temperature

t thermal time constant for the protected device (line or cable), set Time constant

The actual temperature of the protected component (line or cable) is calculated byadding the ambient temperature to the calculated temperature, as shown above. Theambient temperature can be given a constant value or it can be measured. Thecalculated component temperature can be monitored as it is exported from thefunction as a real figure.

When the component temperature reaches the set alarm level Alarm value, theoutput signal ALARM is set. When the component temperature reaches the set triplevel Maximum temperature, the OPERATE output is activated. The OPERATEsignal pulse length is fixed to 100 ms

There is also a calculation of the present time to operation with the present current.This calculation is only performed if the final temperature is calculated to be abovethe operation temperature:

toperatefinal operate

final n

= − ⋅−

−

τ lnΘ Θ

Θ Θ


Caused by the thermal overload protection function, there can be a lockout toreconnect the tripped circuit after operating. The lockout output BLK_CLOSE isactivated at the same time when the OPERATE output is activated and is not resetuntil the device temperature has cooled down below the set value of the Reclosetemperature setting. The Maximum temperature value must be set at least twodegrees above the set value of Reclose temperature.

The time to lockout release is calculated, that is, the calculation of the cooling timeto a set value. The calculated temperature can be reset to its initial value (the Initialtemperature setting) via a control parameter that is located under the clear menu.This is useful during testing when secondary injected current has given a calculatedfalse temperature level.



tlockout release

final lockout release

final n

_

_ln= − ⋅

−

−

τΘ Θ

Θ Θ


Here the final temperature is equal to the set or measured ambient temperature.

In some applications, the measured current can involve a number of parallel lines.This is often used for cable lines where one bay connects several parallel cables.By setting the Current multiplier parameter to the number of parallel lines (cables),the actual current on one line is used in the protection algorithm. To activate thisoption, the ENA_MULT input must be activated.

The ambient temperature can be measured with the RTD measurement. Themeasured temperature value is then connected, for example, from the AI_VAL3output of the X130 (RTD) function to the AMB_TEMP input of T1PTTR.

The Env temperature Set setting is used to define the ambient temperature if theambient temperature measurement value is not connected to the AMB_TEMP input.The Env temperature Set setting is also used when the ambient temperaturemeasurement connected to T1PTTR is set to “Not in use” in the X130 (RTD) function.

The temperature calculation is initiated from the value defined with the Initialtemperature setting parameter. This is done in case the IED is powered up, thefunction is turned "Off" and back "On" or reset through the Clear menu. Thetemperature is also stored in the nonvolatile memory and restored in case the IEDis restarted.

The thermal time constant of the protected circuit is given in seconds with the Timeconstant setting. Please see cable manufacturers manuals for further details.

4.1.3.5 Application

The lines and cables in the power system are constructed for a certain maximumload current level. If the current exceeds this level, the losses will be higher thanexpected. As a consequence, the temperature of the conductors will increase. If thetemperature of the lines and cables reaches too high values, it can cause a risk ofdamages by, for example, the following ways:

• The sag of overhead lines can reach an unacceptable value.• If the temperature of conductors, for example aluminium conductors, becomes

too high, the material will be destroyed.• In cables the insulation can be damaged as a consequence of overtemperature,

and therefore phase-to-phase or phase-to-earth faults can occur.

In stressed situations in the power system, the lines and cables may be required tobe overloaded for a limited time. This should be done without any risk for the above-mentioned risks.



The thermal overload protection provides information that makes temporaryoverloading of cables and lines possible. The thermal overload protection estimatesthe conductor temperature continuously. This estimation is made by using athermal model of the line/cable that is based on the current measurement.

If the temperature of the protected object reaches a set warning level, a signal isgiven to the operator. This enables actions in the power system to be done beforedangerous temperatures are reached. If the temperature continues to increase to themaximum allowed temperature value, the protection initiates a trip of the protectedline.

4.1.3.6 Signals

Table 191: T1PTTR Input signals




ENA_MULT BOOLEAN 0=False Enable Current multiplier

BLK_OPR BOOLEAN 0=False Block signal for operate outputs

TEMP_AMB FLOAT32 0 The ambient temperature used in the calculation

Table 192: T1PTTR Output signals


START BOOLEAN Start

ALARM BOOLEAN Thermal Alarm

BLK_CLOSE BOOLEAN Thermal overload indicator. To inhibite reclose.

4.1.3.7 Settings

Table 193: T1PTTR Group settings

Parameter Values (Range) Unit Step Default DescriptionEnv temperature Set -50...100 °C 1 40 Ambient temperature used when no

external temperature measurementavailable

Current multiplier 1...5 1 1 Current multiplier when function is usedfor parallel lines

Current reference 0.05...4.00 xIn 0.01 1.00 The load current leading to Temperatureraise temperature

Temperature rise 0.0...200.0 °C 0.1 75.0 End temperature rise above ambient

Time constant 60...60000 s 1 2700 Time constant of the line in seconds.




Parameter Values (Range) Unit Step Default DescriptionMaximum temperature 20.0...200.0 °C 0.1 90.0 Temperature level for operate

Alarm value 20.0...150.0 °C 0.1 80.0 Temperature level for start (alarm)

Reclose temperature 20.0...150.0 °C 0.1 70.0 Temperature for reset of block recloseafter operate

Table 194: T1PTTR Non group settings



Initial temperature -50.0...100.0 °C 0.1 0.0 Temperature raise above ambienttemperature at startup


Table 195: T1PTTR Monitored data

Name Type Values (Range) Unit DescriptionTEMP FLOAT32 -100.0...9999.9 °C The calculated

temperature of theprotected object

TEMP_RL FLOAT32 0.00...99.99 The calculatedtemperature of theprotected object relativeto the operate level

T_OPERATE INT32 0...60000 s Estimated time to operate

T_ENA_CLOSE INT32 0...60000 s Estimated time todeactivate BLK_CLOSE

T1PTTR Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 196: T1PTTR Technical data


measured: fn ±2 Hz

Current measurement: ±1.5% of the set value or±0.002 x In (at currents in the range of0.01...4.00 x In)

Operate time accuracy1) ±2.0% of the theoretical value or ±0.50 s

1) Overload current > 1.2 x Operate level temperature




Table 197: T1PTTR Technical revision history

Technical revision ChangeC Removed the Sensor available setting parameter

D Added the AMB_TEMP input

4.1.4 Three-phase thermal overload protection for powertransformers, two time constants T2PTTR





Three-phase thermal overloadprotection for power transformers, twotime constants

T2PTTR 3Ith>T 49T


GUID-68AADF30-9DC7-49D5-8C77-14E774C8D1AF V2 EN



The three-phase thermal overload, two time constant protection function T2PTTRprotects the transformer mainly from short-time overloads. The transformer isprotected from long-time overloads with the oil temperature detector included in itsequipment.

The alarm signal gives an early warning to allow the operators to take action beforethe transformer trips. The early warning is based on the three-phase currentmeasuring function using a thermal model with two settable time constants. If thetemperature rise continues, T2PTTR operates based on the thermal model of thetransformer.

After a thermal overload operation, the re-energizing of the transformer is inhibitedduring the transformer cooling time. The transformer cooling is estimated with athermal model.





The operation of the three-phase thermal overload, two time constant protection forpower transformers can be described using a module diagram. All the modules inthe diagram are explained in the next sections.

ALARM

OPERATE

BLK_CLOSE

I_A Max current selector

I_BI_C

BLOCK

Thermal counter

Temperature estimator

START

AMB_TEMPGUID-FF965F1C-6039-4A01-9A4F-B378F8356279 V2 EN


Max current selectorThe max current selector of the function continuously checks the highest measuredTRMS phase current value. The selector reports the highest value to the thermalcounter.

Temperature estimatorThe final temperature rise is calculated from the highest of the three-phase currentsaccording to the expression:

Θ final

ref

ref

I

IT=

⋅

2

GUID-06DE6459-E94A-4FC7-8357-CA58988CEE97 V2 EN (Equation 6)

I highest measured phase current

Iref the set value of the Current reference setting

Tref the set value of the Temperature rise setting (temperature rise (°C) with the steady-state currentIref

The ambient temperature value is added to the calculated final temperature riseestimation. If the total value of temperature is higher than the set operatetemperature level, the START output is activated.

The Current reference setting is a steady-state current that gives the steady-stateend temperature value Temperature rise. It gives a setting value corresponding tothe rated power of the transformer.



The Temperature rise setting is used when the value of the reference temperaturerise corresponds to the Current reference value. The temperature values with thecorresponding transformer load currents are usually given by transformermanufacturers.

Thermal counterT2PTTR applies the thermal model of two time constants for temperaturemeasurement. The temperature rise in degrees Celsius (°C) is calculated from thehighest of the three-phase currents according to the expression:

∆Θ

∆

=

⋅ −

+ −( ) ⋅

−

pI

IT e p

refref

t

* *

2

11 1τII

IT e

refref

t

⋅

⋅ −

−2

21

∆

τ

GUID-27A879A9-AF94-4BC3-BAA1-501189F6DE0C V2 EN (Equation 7)

ΔΘ calculated temperature rise (°C) in transformer

I measured phase current with the highest TRMS value

Iref the set value of the Current reference setting (rated current of the protected object)

Tref the set value of the Temperature rise setting (temperature rise setting (°C) with the steady-statecurrent Iref)

p the set value of the Weighting factor p setting (weighting factor for the short time constant)

Δt time step between the calculation of the actual temperature

t1 the set value of the Short time constant setting (the short heating / cooling time constant)

t2 the set value of the Long time constant setting (the long heating / cooling time constant)

The warming and cooling following the two time-constant thermal curve is acharacteristic of transformers. The thermal time constants of the protectedtransformer are given in seconds with the Short time constant and Long timeconstant settings. The Short time constant setting describes the warming of thetransformer with respect to windings. The Long time constant setting describes thewarming of the transformer with respect to the oil. Using the two time-constantmodel, the IED is able to follow both fast and slow changes in the temperature ofthe protected object.

The Weighting factor p setting is the weighting factor between Short time constantτ1 and Long time constant τ2. The higher the value of the Weighting factor psetting, the larger is the share of the steep part of the heating curve. WhenWeighting factor p =1, only Short-time constant is used. When Weighting factor p= 0, only Long time constant is used.



GUID-E040FFF4-7FE3-4736-8E5F-D96DB1F1B16B V1 EN

Figure 88: Effect of the Weighting factor p factor and the difference betweenthe two time constants and one time constant models

The actual temperature of the transformer is calculated by adding the ambienttemperature to the calculated temperature.

Θ Θ Θ= ∆ +amb

GUID-77E49346-66D2-4CAB-A764-E81D6F382E74 V2 EN (Equation 8)

Θ temperature in transformer (°C)

ΔΘ calculated temperature rise (°C) in transformer

Θamb set value of the Env temperature Set setting or measured ambient temperature

The ambient temperature can be measured with RTD measurement. The measuredtemperature value is connected, for example, from the AI_VAL3 output of theX130 (RTD) function to the AMB_TEMP input of T2PTTR.

The Env temperature Set setting is used to define the ambient temperature if theambient temperature measurement value is not connected to the AMB_TEMP input.The Env temperature Set setting is also used when the ambient temperaturemeasurement connected to T2PTTR is set to “Not in use” in the X130 (RTD) function.

The temperature calculation is initiated from the value defined with the Initialtemperature and Max temperature setting parameters. The initial value is apercentage of Max temperature defined by Initial temperature. This is done whenthe IED is powered up or the function is turned off and back on or reset through the



Clear menu. The temperature is stored in a nonvolatile memory and restored if theIED is restarted.

The Max temperature setting defines the maximum temperature of the transformerin degrees Celsius (°C). The value of the Max temperature setting is usually givenby transformer manufacturers. The actual alarm, operating and lockouttemperatures for T2PTTR are given as a percentage value of the Max temperaturesetting.

When the transformer temperature reaches the alarm level defined with the Alarmtemperature setting, the ALARM output signal is set. When the transformertemperature reaches the trip level value defined with the Operate temperaturesetting, the OPERATE output is activated. The OPERATE output is deactivatedwhen the value of the measured current falls below 10 percent of the CurrentReference value or the calculated temperature value falls below Operatetemperature.

There is also a calculation of the present time to operation with the present current.T_OPERATE is only calculated if the final temperature is calculated to be abovethe operation temperature. The value is available in the monitored data view.

After operating, there can be a lockout to reconnect the tripped circuit due to thethermal overload protection function. The BLK_CLOSE lockout output is activatedwhen the device temperature is above the Reclose temperature lockout releasetemperature setting value. The time to lockout release T_ENA_CLOSE is alsocalculated. The value is available in the monitored data view.

4.1.4.5 Application

The transformers in a power system are constructed for a certain maximum loadcurrent level. If the current exceeds this level, the losses are higher than expected.This results in a rise in transformer temperature. If the temperature rise is too high,the equipment is damaged:

• Insulation within the transformer ages faster, which in turn increases the riskof internal phase-to-phase or phase-to-earth faults.

• Possible hotspots forming within the transformer degrade the quality of thetransformer oil.

During stressed situations in power systems, it is required to overload thetransformers for a limited time without any risks. The thermal overload protectionprovides information and makes temporary overloading of transformers possible.

The permissible load level of a power transformer is highly dependent on thetransformer cooling system. The two main principles are:



• ONAN: The air is naturally circulated to the coolers without fans, and the oil isnaturally circulated without pumps.

• OFAF: The coolers have fans to force air for cooling, and pumps to force thecirculation of the transformer oil.

The protection has several parameter sets located in the setting groups, for exampleone for a non-forced cooling and one for a forced cooling situation. Both thepermissive steady-state loading level as well as the thermal time constant areinfluenced by the transformer cooling system. The active setting group can bechanged by a parameter, or through a binary input if the binary input is enabled forit. This feature can be used for transformers where forced cooling is taken out ofoperation or extra cooling is switched on. The parameters can also be changedwhen a fan or pump fails to operate.

The thermal overload protection continuously estimates the internal heat content,that is, the temperature of the transformer. This estimation is made by using athermal model of the transformer which is based on the current measurement.

If the heat content of the protected transformer reaches the set alarm level, a signalis given to the operator. This enables the action that needs to be taken in the powersystems before the temperature reaches a high value. If the temperature continuesto rise to the trip value, the protection initiates the trip of the protected transformer.

After the trip, the transformer needs to cool down to a temperature level where thetransformer can be taken into service again. T2PTTR continues to estimate the heatcontent of the transformer during this cooling period using a set cooling timeconstant. The energizing of the transformer is blocked until the heat content isreduced to the set level.

The thermal curve of two time constants is typical for a transformer. The thermaltime constants of the protected transformer are given in seconds with the Short timeconstant and Long time constant settings. If the manufacturer does not state anyother value, the Long time constant can be set to 4920 s (82 minutes) for adistribution transformer and 7260 s (121 minutes) for a supply transformer. Thecorresponding Short time constants are 306 s (5.1 minutes) and 456 s (7.6 minutes).

If the manufacturer of the power transformer has stated only one, that is, a singletime constant, it can be converted to two time constants. The single time constant isalso used by itself if the p-factor Weighting factor p setting is set to zero and thetime constant value is set to the value of the Long time constant setting. Thethermal image corresponds to the one time constant model in that case.

Table 198: Conversion table between one and two time constants

Single time constant(min)

Short time constant (min) Long time constant (min) Weighting factor p

10 1.1 17 0.4

15 1.6 25 0.4

20 2.1 33 0.4




Single time constant(min)

Short time constant (min) Long time constant (min) Weighting factor p

25 2.6 41 0.4

30 3.1 49 0.4

35 3.6 58 0.4

40 4.1 60 0.4

45 4.8 75 0.4

50 5.1 82 0.4

55 5.6 90 0.4

60 6.1 98 0.4

65 6.7 107 0.4

70 7.2 115 0.4

75 7.8 124 0.4

The default Max temperature setting is 105°C. This value is chosen since eventhough the IEC 60076-7 standard recommends 98°C as the maximum allowabletemperature in long-time loading, the standard also states that a transformer canwithstand the emergency loading for weeks or even months, which may producethe winding temperature of 140°C. Therefore, 105°C is a safe maximumtemperature value for a transformer if the Max temperature setting value is notgiven by the transformer manufacturer.

4.1.4.6 Signals

Table 199: T2PTTR Input signals






Table 200: T2PTTR Output signals


START BOOLEAN Start


BLK_CLOSE BOOLEAN Thermal overload indicator. To inhibite reclose.



4.1.4.7 Settings

Table 201: T2PTTR Group settings

Parameter Values (Range) Unit Step Default DescriptionEnv temperature Set -50...100 °C 1 40 Ambient temperature used when no

external temperature measurementavailable

Current reference 0.05...4.00 xIn 0.01 1.00 The load current leading to Temperatureraise temperature

Temperature rise 0.0...200.0 °C 0.1 78.0 End temperature rise above ambient

Max temperature 0.0...200.0 °C 0.1 105.0 Maximum temperature allowed for thetransformer

Operate temperature 80.0...120.0 % 0.1 100.0 Operate temperature, percent value

Alarm temperature 40.0...100.0 % 0.1 90.0 Alarm temperature, percent value

Reclose temperature 40.0...100.0 % 0.1 60.0 Temperature for reset of block recloseafter operate

Short time constant 6...60000 s 1 450 Short time constant in seconds

Long time constant 60...60000 s 1 7200 Long time constant in seconds

Weighting factor p 0.00...1.00 0.01 0.40 Weighting factor of the short time constant

Table 202: T2PTTR Non group settings



Initial temperature 0.0...100.0 % 0.1 80.0 Initial temperature, percent value


Table 203: T2PTTR Monitored data

Name Type Values (Range) Unit DescriptionTEMP FLOAT32 -100.0...9999.9 °C The calculated

temperature of theprotected object

TEMP_RL FLOAT32 0.00...99.99 The calculatedtemperature of theprotected object relativeto the operate level

T_OPERATE INT32 0...60000 s Estimated time to operate

T_ENA_CLOSE INT32 0...60000 s Estimated time todeactivate BLK_CLOSEin seconds

T2PTTR Enum 1=on2=blocked3=test4=test/blocked5=off

Status




Table 204: T2PTTR Technical data


measured: fn ±2 Hz





Table 205: T2PTTR Technical revision history

Technical revision ChangeB Added the AMB_TEMP input

4.1.5 Motor load jam protection JAMPTOC





Motor load jam protection JAMPTOC Ist> 51LR


GUID-FA5FAB32-8730-4985-B228-11B92DD9E626 V2 EN



The motor load jam protection JAMPTOC is used for protecting the motor in stallor mechanical jam situations during the running state.

When the motor is started, a separate function is used for the startup protection, andJAMPTOC is normally blocked during the startup period. When the motor haspassed the starting phase, JAMPTOC monitors the magnitude of phase currents.



The function starts when the measured current exceeds the breakdown torque level,that is, above the set limit. The operation characteristic is definite time.

The function contains a blocking functionality. It is possible to block the functionoutputs.



The operation of the motor load jam protection can be described with a modulediagram. All the modules in the diagram are explained in the next sections.

GUID-93025A7F-12BE-4ACD-8BD3-C144CB73F65A V2 EN


Level detectorThe measured phase currents are compared to the set Start value. The TRMSvalues of the phase currents are considered for the level detection. The timermodule is enabled if at least two of the measured phase currents exceed the setStart value.

TimerOnce activated, the internal START signal is activated. The value is available onlythrough the Monitored data view. The time characteristic is according to DT. Whenthe operation timer has reached the Operate delay time value, the OPERATE outputis activated.

When the timer has elapsed but the motor stall condition still exists, the OPERATEoutput remains active until the phase currents values drop below the Start value,that is, until the stall condition persists. If the drop-off situation occurs while theoperating time is still counting, the reset timer is activated. If the drop-off timeexceeds the set Reset delay time, the operating timer is reset.






4.1.5.5 Application

The motor protection during stall is primarily needed to protect the motor fromexcessive temperature rise, as the motor draws large currents during the stall phase.This condition causes a temperature rise in the stator windings. Due to reducedspeed, the temperature also rises in the rotor. The rotor temperature rise is morecritical when the motor stops.

The physical and dielectric insulations of the system deteriorate with age and thedeterioration is accelerated by the temperature increase. Insulation life is related tothe time interval during which the insulation is maintained at a given temperature.

An induction motor stalls when the load torque value exceeds the breakdowntorque value, causing the speed to decrease to zero or to some stable operatingpoint well below the rated speed. This occurs, for example, when the applied shaftload is suddenly increased and is greater than the producing motor torque due tothe bearing failures. This condition develops a motor current almost equal to thevalue of the locked-rotor current.

JAMPTOC is designed to protect the motor in stall or mechanical jam situationsduring the running state. To provide a good and reliable protection for motors in astall situation, the temperature effects on the motor have to be kept within theallowed limits.

4.1.5.6 Signals

Table 206: JAMPTOC Input signals







Table 207: JAMPTOC Output signals


4.1.5.7 Settings

Table 208: JAMPTOC Non group settings



Start value 0.10...10.00 xIn 0.01 2.50 Start value




Table 209: JAMPTOC Monitored data

Name Type Values (Range) Unit DescriptionSTART BOOLEAN 0=False

1=True Start

START_DUR FLOAT32 0.00...100.00 % Ratio of start time /operate time

JAMPTOC Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 210: JAMPTOC Technical data


measured: fn ±2 Hz

±1.5% of the set value or ±0.002 x In

Reset time < 40 ms






4.1.6 Loss of load supervision LOFLPTUC





Loss of load supervision LOFLPTUC 3I< 37


GUID-B7774D44-24DB-48B1-888B-D9E3EA741F23 V2 EN



The loss of load supervision LOFLPTUC is used to detect a sudden load loss whichis considered as a fault condition.

LOFLPTUC starts when the current is less than the set limit. It operates with thedefinite time (DT) characteristics, which means that the function operates after apredefined operate time and resets when the fault current disappears.

The function contains a blocking functionality. It is possible to block functionoutputs, the definite timer or the function itself, if desired.



The operation of the loss of load supervision can be described using a modulediagram. All the modules in the diagram are explained in the next sections.

GUID-4A6308B8-47E8-498D-A268-1386EBBBEC8F V1 EN




Level detector 1This module compares the phase currents (RMS value) to the set Start value highsetting. If all the phase current values are less than the set Start value high value,the loss of load condition is detected and an enable signal is sent to the timer. Thissignal is disabled after one or several phase currents have exceeded the set Startvalue high value of the element.

Level detector 2This is a low-current detection module, which monitors the de-energized conditionof the motor. It compares the phase currents (RMS value) to the set Start value lowsetting. If any of the phase current values is less than the set Start value low, asignal is sent to block the operation of the timer.

TimerOnce activated, the timer activates the START output. The time characteristic isaccording to DT. When the operation timer has reached the value set by Operatedelay time, the OPERATE output is activated. If the fault disappears before themodule operates, the reset timer is activated. If the reset timer reaches the value setby Reset delay time, the operate timer resets and the START output is deactivated.


The BLOCK signal blocks the operation of the function and resets the timer.

4.1.6.5 Application

When a motor runs with a load connected, it draws a current equal to a valuebetween the no-load value and the rated current of the motor. The minimum loadcurrent can be determined by studying the characteristics of the connected load.When the current drawn by the motor is less than the minimum load current drawn,it can be inferred that the motor is either disconnected from the load or thecoupling mechanism is faulty. If the motor is allowed to run in this condition, itmay aggravate the fault in the coupling mechanism or harm the personnel handlingthe machine. Therefore, the motor has to be disconnected from the power supply assoon as the above condition is detected.

LOFLPTUC detects the condition by monitoring the current values and helpsdisconnect the motor from the power supply instantaneously or after a delayaccording to the requirement.

When the motor is at standstill, the current will be zero and it is not recommendedto activate the trip during this time. The minimum current drawn by the motorwhen it is connected to the power supply is the no load current, that is, the higherstart value current. If the current drawn is below the lower start value current, themotor is disconnected from the power supply. LOFLPTUC detects this condition



and interprets that the motor is de-energized and disables the function to preventunnecessary trip events.

4.1.6.6 Signals

Table 211: LOFLPTUC Input signals




BLOCK BOOLEAN 0=False Block all binary outputs by resetting timers

Table 212: LOFLPTUC Output signals


START BOOLEAN Start

4.1.6.7 Settings

Table 213: LOFLPTUC Group settings

Parameter Values (Range) Unit Step Default DescriptionStart value low 0.01...0.50 xIn 0.01 0.10 Current setting/Start value low

Start value high 0.01...1.00 xIn 0.01 0.50 Current setting/Start value high


Table 214: LOFLPTUC Non group settings





Table 215: LOFLPTUC Monitored data


operate time

LOFLPTUC Enum 1=on2=blocked3=test4=test/blocked5=off

Status




Table 216: LOFLPTUC Technical data


measured: fn ±2 Hz


Start time Typical 300 ms

Reset time < 40 ms




4.1.7 Thermal overload protection for motors MPTTR





Thermal overload protection for motors MPTTR 3Ith>M 49M


GUID-1EEED1E9-3A6F-4EF3-BDCC-990E648E2E72 V4 EN



The thermal overload protection for motors function MPTTR protects the electricmotors from overheating. MPTTR models the thermal behavior of motor on thebasis of the measured load current and disconnects the motor when the thermalcontent reaches 100 percent. The thermal overload conditions are the most oftenencountered abnormal conditions in industrial motor applications. The thermaloverload conditions are typically the result of an abnormal rise in the motorrunning current, which produces an increase in the thermal dissipation of the motorand temperature or reduces cooling. MPTTR prevents an electric motor from



drawing excessive current and overheating, which causes the premature insulationfailures of the windings and, in worst cases, burning out of the motors.



The operation of the motor thermal overload protection function can be describedusing a module diagram. All the modules in the diagram are explained in the nextsections.

ALARMBLK_RESTART

Max current selector

I_A

Thermal level

calculatorInternal

FLC calculator

Alarm and tripping

logic

START_EMERGBLOCK

OPERATE

I_BI_C

I2

AMB_TEMP

GUID-1E5F2337-DA4E-4F5B-8BEB-27353A6734DC V2 EN


Max current selectorMax current selector selects the highest measured TRMS phase current and reportsit to Thermal level calculator.

Internal FLC calculatorFull load current (FLC) of the motor is defined by the manufacturer at an ambienttemperature of 40°C. Special considerations are required with an application wherethe ambient temperature of a motor exceeds or remains below 40°C. A motoroperating at a higher temperature, even if at or below rated load, can subject themotor windings to excessive temperature similar to that resulting from overloadoperation at normal ambient temperature. The motor rating has to be appropriatelyreduced for operation in such high ambient temperatures. Similarly, when theambient temperature is considerably lower than the nominal 40°C, the motor canbe slightly overloaded. For calculating thermal level it is better that the FLC valuesare scaled for different temperatures. The scaled currents are known as internalFLC. An internal FLC is calculated based on the ambient temperature shown in thetable. The Env temperature mode setting defines whether the thermal levelcalculations are based on FLC or internal FLC.

When the value of the Env temperature mode setting is set to the "FLC Only"mode, no internal FLC is calculated. Instead, the FLC given in the data sheet of themanufacturer is used. When the value of the Env temperature mode setting is set to"Set Amb Temp" mode, the internal FLC is calculated based on the ambienttemperature taken as an input through the Env temperature Set setting. When the



Env temperature mode setting is on "Use input" mode, the internal FLC iscalculated from temperature data available through resistance temperature detectors(RTDs) using the AMB_TEMP input.

Table 217: Modification of internal FLC

Ambient Temperature Tamb Internal FLC

<20°C FLC x 1.09

20 to <40°C FLC x (1.18 - Tamb x 0.09/20)

40°C FLC

>40 to 65°C FLC x (1 –[(Tamb -40)/100])

>65°C FLC x 0.75

The ambient temperature is used for calculating thermal level and it is available inthe monitored data view from the TEMP_AMB output. The activation of the BLOCKinput does not affect the TEMP_AMB output.

The Env temperature Set setting is used:

• If the ambient temperature measurement value is not connected to theAMB_TEMP input in ACT.

• When the ambient temperature measurement connected to 49M is set to Not inuse in the RTD function.

• In case of any errors or malfunctioning in the RTD output.

Thermal level calculatorThe module calculates the thermal load considering the TRMS and negative-sequence currents. The heating up of the motor is determined by the square valueof the load current.

However, in case of unbalanced phase currents, the negative-sequence current alsocauses additional heating. By deploying a protection based on both currentcomponents, abnormal heating of the motor is avoided.

The thermal load is calculated based on different situations or operations and it alsodepends on the phase current level. The equations used for the heating calculationsare:

θτ

Br r

tI

k IK

I

k Ie p=

×

+ ×

×

× −( )×

−

2

22

2

1/

%

GUID-526B455A-67DD-46E7-813D-A64EC619F6D7 V2 EN (Equation 9)

θτ

A

r r

tI

k IK

I

k Ie=

×

+ ×

×

× −( )×

−

2

22

2

1 100/

%

GUID-9C893D3E-7CAF-4EA6-B92D-C914288D7CFC V2 EN (Equation 10)



I TRMS value of the measured max of phase currents

Ir set Rated current, FLC or internal FLC

I2 measured negative sequence current

k set value of Overload factor

K2 set value of Negative Seq factor

p set value of Weighting factor

t time constant

The equation θB is used when the values of all the phase currents are below theoverload limit, that is, k x Ir. The equation θA is used when the value of any one ofthe phase currents exceeds the overload limit.

During overload condition, the thermal level calculator calculates the value of θB inbackground, and when the overload ends the thermal level is brought linearly fromθA to θB with a speed of 1.66 percent per second. For the motor at standstill, that is,when the current is below the value of 0.12 x Ir, the cooling is expressed as:

θ θ τ= ×

−

02 e

t

GUID-2C640EA9-DF69-42A9-A6A8-3CD20AEC76BD V2 EN (Equation 11)

θ02 initial thermal level when cooling begins

GUID-A19F9DF2-2F04-401F-AE7A-6CE55F88EB1D V2 EN

Figure 95: Thermal behavior

The required overload factor and negative sequence current heating effect factorare set by the values of the Overload factor and Negative Seq factor settings.

In order to accurately calculate the motor thermal condition, different timeconstants are used in the above equations. These time constants are employedbased on different motor running conditions, for example starting, normal or stop,



and are set through the Time constant start, Time constant normal and Timeconstant stop settings. Only one time constant is valid at a time.

Table 218: Time constant and the respective phase current values

Time constant (tau) in use Phase currentTime constant start Any current whose value is over 2.5 x Ir

Time constant normal Any current whose value is over 0.12 x Ir and allcurrents are below 2.5 x Ir

Time constant stop All the currents whose values are below 0.12 x Ir

The Weighting factor p setting determines the ratio of the thermal increase of thetwo curves θA and θB.

The thermal level at the power-up of the IED is defined by the Initial thermal Valsetting.

The temperature calculation is initiated from the value defined in the Initialthermal Val setting. This is done if the IED is powered up or the function is turnedoff and back on or reset through the Clear menu.

The calculated temperature of the protected object relative to the operate level, theTEMP_RL output, is available through the monitored data view. The activation ofthe BLOCK input does not affect the calculated temperature.

The thermal level at the beginning of the startup condition of a motor and at theend of the startup condition is available in the monitored data view at theTHERMLEV_ST and THERMLEV_END outputs respectively. The activation of theBLOCK input does not have any effect on these outputs.

Alarm and tripping logicThe module generates alarm, restart inhibit and tripping signals.

When the thermal level exceeds the set value of the Alarm thermal value setting,the ALARM output is activated. Sometimes a condition arises when it becomesnecessary to inhibit the restarting of a motor, for example in case of some extremestarting condition like long starting time. If the thermal content exceeds the setvalue of the Restart thermal val setting, the BLK_RESTART output is activated.The time for the next possible motor startup is available through the monitored dataview from the T_ENARESTART output. The T_ENARESTART output estimatesthe time for the BLK_RESTART deactivation considering as if the motor is stopped.

When the emergency start signal START_EMERG is set high, the thermal level isset to a value below the thermal restart inhibit level. This allows at least one motorstartup, even though the thermal level has exceeded the restart inhibit level.



When the thermal content reaches 100 percent, the OPERATE output is activated.The OPERATE output is deactivated when the value of the measured current fallsbelow 12 percent of Rated current or the thermal content drops below 100 percent.

The activation of the BLOCK input blocks the ALARM, BLK_RESTART andOPERATE outputs.



Tau

3840

1920

960

640

480

320

160

80

[s]

GUID-F3D1E6D3-86E9-4C0A-BD43-350003A07292 V1 EN

Figure 96: Trip curves when no prior load and p=20...100 %. Overload factor= 1.05.



Tau

3840

1920

96080 160 320 480 640

[s]

GUID-44A67C51-E35D-4335-BDBD-5CD0D3F41EF1 V1 EN

Figure 97: Trip curves at prior load 1 x FLC and p=100 %, Overload factor =1.05.



Tau

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1920

960

640

480

320

16080

[s]

GUID-5CB18A7C-54FC-4836-9049-0CE926F35ADF V1 EN

Figure 98: Trip curves at prior load 1 x FLC and p=50 %. Overload factor = 1.05.



4.1.7.5 Application

MPTTR is intended to limit the motor thermal level to predetermined values duringthe abnormal motor operating conditions. This prevents a premature motorinsulation failure.

The abnormal conditions result in overheating and include overload, stalling,failure to start, high ambient temperature, restricted motor ventilation, reducedspeed operation, frequent starting or jogging, high or low line voltage or frequency,mechanical failure of the driven load, improper installation and unbalanced linevoltage or single phasing. The protection of insulation failure by theimplementation of current sensing cannot detect some of these conditions, such asrestricted ventilation. Similarly, the protection by sensing temperature alone can beinadequate in cases like frequent starting or jogging. The thermal overloadprotection addresses these deficiencies to a larger extent by deploying a motorthermal model based on load current.

The thermal load is calculated using the true RMS phase value and negativesequence value of the current. The heating up of the motor is determined by thesquare value of the load current. However, while calculating the thermal level, therated current should be re-rated or de-rated depending on the value of the ambienttemperature. Apart from current, the rate at which motor heats up or cools isgoverned by the time constant of the motor.

Setting the weighting factorThere are two thermal curves: one which characterizes the short-time loads and long-time overloads and which is also used for tripping and another which is used formonitoring the thermal condition of the motor. The value of the Weighting factor psetting determines the ratio of the thermal increase of the two curves.

When the Weighting factor p setting is 100 percent, a pure single time constantthermal unit is produced which is used for application with the cables. As presentedin Figure 99, the hot curve with the value of Weighting factor p being 100 percentonly allows an operate time which is about 10 percent of that with no prior load.For example, when the set time constant is 640 seconds, the operate time with theprior load 1 x FLC (full Load Current) and overload factor 1.05 is only 2 seconds,even if the motor could withstand at least 5 to 6 seconds. To allow the use of thefull capacity of the motor, a lower value of Weighting factor p should be used.

Normally, an approximate value of half of the thermal capacity is used when themotor is running at full load. Thus by setting Weighting factor p to 50 percent, theIED notifies a 45 to 50 percent thermal capacity use at full load.

For direct-on-line started motors with hot spot tendencies, the value of Weightingfactor p is typically set to 50 percent, which will properly distinguish between short-time thermal stress and long-time thermal history. After a short period of thermalstress, for example a motor startup, the thermal level starts to decrease quitesharply, simulating the leveling out of the hot spots. Consequently, the probabilityof successive allowed startups increases.



When protecting the objects without hot spot tendencies, for example motorsstarted with soft starters, and cables, the value of Weighting factor p is set to 100percent. With the value of Weighting factor p set to 100 percent, the thermal leveldecreases slowly after a heavy load condition. This makes the protection suitablefor applications where no hot spots are expected. Only in special cases where thethermal overload protection is required to follow the characteristics of the object tobe protected more closely and the thermal capacity of the object is very wellknown, a value between 50 and 100 percent is required.

For motor applications where, for example, two hot starts are allowed instead ofthree cold starts, the value of the setting Weighting factor p being 40 percent hasproven to be useful. Setting the value of Weighting factor p significantly below 50percent should be handled carefully as there is a possibility to overload theprotected object as a thermal unit might allow too many hot starts or the thermalhistory of the motor has not been taken into account sufficiently.



t/s

1000

100

500

200

50

10

20

5

1

2

3

4

30

40

300

400

2000

3000

4000

1 2 3 4 5 106 8 I/Iq

1.05

p[%]

20

50

75

100

x

Cold

curve

GUID-B6F9E655-4FFC-4B06-841A-68DADE785BF2 V1 EN

Figure 99: The influence of Weighting factor p at prior load 1xFLC,timeconstant = 640 sec, and Overload factor = 1.05



Setting the overload factorThe value of Overload factor defines the highest permissible continuous load. Therecommended value is 1.05.

Setting the negative sequence factorDuring the unbalance condition, the symmetry of the stator currents is disturbedand a counter-rotating negative sequence component current is set up. An increasedstator current causes additional heating in the stator and the negative sequencecomponent current excessive heating in the rotor. Also mechanical problems likerotor vibration can occur.

The most common cause of unbalance for three-phase motors is the loss of phaseresulting in an open fuse, connector or conductor. Often mechanical problems canbe more severe than the heating effects and therefore a separate unbalanceprotection is used.

Unbalances in other connected loads in the same busbar can also affect the motor.A voltage unbalance typically produces 5 to 7 times higher current unbalance.Because the thermal overload protection is based on the highest TRMS value of thephase current, the additional heating in stator winding is automatically taken intoaccount. For more accurate thermal modeling, the Negative Seq factor setting isused for taking account of the rotor heating effect.

Negative Seq factorR

R

R

R

=2

1

GUID-EA5AD510-A3CA-47FB-91F0-75D7272B654E V1 EN (Equation 12)

RR2 rotor negative sequence resistance

RR1 rotor positive sequence resistance

A conservative estimate for the setting can be calculated:

Negative Seq factorILR

=

175

2

GUID-13CE37C5-295F-41D4-8159-400FA377C84C V1 EN

ILR locked rotor current (multiple of set Rated current). The same as the startup current at thebeginning of the motor startup.

For example, if the rated current of a motor is 230 A, startup current is 5.7 x Ir,

Negative Seq factor = =

175

5 75 4

2.

.

GUID-DF682702-E6B1-4814-8B2E-31C28F3A03DF V1 EN



Setting the thermal restart levelThe restart disable level can be calculated as follows:

θistartup timeof the motor

operate time when no prior load= − ×100 10% 00% +

margin

GUID-5B3B714D-8C58-4C5D-910D-A23852BC8B15 V1 EN (Equation 13)

For example, the motor startup time is 11 seconds, start-up current 6 x rated andTime constant start is set for 800 seconds. Using the trip curve with no prior load,the operation time at 6 x rated current is 25 seconds, one motor startup uses 11/25≈ 45 percent of the thermal capacity of the motor. Therefore, the restart disablelevel must be set to below 100 percent - 45 percent = 55 percent, for example to 50percent (100 percent - (45 percent + margin), where margin is 5 percent).

Setting the thermal alarm levelTripping due to high overload is avoided by reducing the load of the motor on aprior alarm.

The value of Alarm thermal value is set to a level which allows the use of the fullthermal capacity of the motor without causing a trip due to a long overload time.Generally, the prior alarm level is set to a value of 80 to 90 percent of the trip level.

4.1.7.6 Signals

Table 219: MPTTR Input signals




I2 SIGNAL 0 Negative sequence current


START_EMERG BOOLEAN 0=False Signal for indicating the need for emergency start


Table 220: MPTTR Output signals



BLK_RESTART BOOLEAN Thermal overload indicator, to inhibit restart



4.1.7.7 Settings

Table 221: MPTTR Group settings

Parameter Values (Range) Unit Step Default DescriptionOverload factor 1.00...1.20 0.01 1.05 Overload factor (k)

Alarm thermal value 50.0...100.0 % 0.1 95.0 Thermal level above which functiongives an alarm

Restart thermal Val 20.0...80.0 % 0.1 40.0 Thermal level above which functioninhibits motor restarting

Negative Seq factor 0.0...10.0 0.1 0.0 Heating effect factor for negativesequence current

Weighting factor p 20.0...100.0 % 0.1 50.0 Weighting factor (p)

Time constant normal 80...4000 s 1 320 Motor time constant during the normaloperation of motor

Time constant start 80...4000 s 1 320 Motor time constant during the start ofmotor

Time constant stop 80...8000 s 1 500 Motor time constant during the standstillcondition of motor

Env temperature mode 1=FLC Only2=Use input3=Set Amb Temp

1=FLC Only Mode of measuring ambient temperature

Env temperature Set -20.0...70.0 °C 0.1 40.0 Ambient temperature used when noexternal temperature measurementavailable

Table 222: MPTTR Non group settings



Rated current 0.30...2.00 xIn 0.01 1.00 Rated current (FLC) of the motor

Initial thermal Val 0.0...100.0 % 0.1 74.0 Initial thermal level of the motor




Table 223: MPTTR Monitored data

Name Type Values (Range) Unit DescriptionTEMP_RL FLOAT32 0.00...9.99 The calculated

temperature of theprotected object relativeto the operate level

THERMLEV_ST FLOAT32 0.00...9.99 Thermal level atbeginning of motorstartup

THERMLEV_END FLOAT32 0.00...9.99 Thermal level at the endof motor startup situation

T_ENARESTART INT32 0...99999 s Estimated time to resetof block restart

MPTTR Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 224: MPTTR Technical data


measured: fn ±2 Hz





Table 225: MPTTR Technical revision history

Technical revision ChangeB Added a new input AMB_TEMP.

Added a new selection for the Env temperaturemode setting "Use input".



4.2 Earth-fault protection

4.2.1 Non-directional earth-fault protection EFxPTOC





Non-directional earth-fault protection -Low stage

EFLPTOC Io> 51N-1

Non-directional earth-fault protection -High stage

EFHPTOC Io>> 51N-2

Non-directional earth-fault protection -Instantaneous stage

EFIPTOC Io>>> 50N/51N


EFLPTOC

Io

BLOCK START

OPERATE

ENA_MULT

EFHPTOC

Io

BLOCK START

OPERATE

ENA_MULT

EFIPTOC

Io

BLOCK START

OPERATE

ENA_MULT

A070432 V2 EN



The earth-fault function EFxPTOC is used as non-directional earth-fault protectionfor feeders.

The function starts and operates when the residual current exceeds the set limit.The operate time characteristic for low stage EFLPTOC and high stage EFHPTOCcan be selected to be either definite time (DT) or inverse definite minimum time(IDMT). The instantaneous stage EFIPTOC always operates with the DTcharacteristic.







The operation of non-directional earth-fault protection can be described by using amodule diagram. All the modules in the diagram are explained in the next sections.

A070437 V3 EN

Figure 101: Functional module diagram. Io represents the residual current.

Level detectorThe operating quantity can be selected with the setting Io signal Sel. The selectableoptions are "Measured Io" and "Calculated Io". The operating quantity is comparedto the set Start value. If the measured value exceeds the set Start value, the leveldetector sends an enable-signal to the timer module. If the ENA_MULT input isactive, the Start value setting is multiplied by the Start value Mult setting.





If a drop-off situation happens, that is, a fault suddenly disappears before theoperate delay is exceeded, the timer reset state is activated. The functionality of thetimer in the reset state depends on the combination of the Operating curve type,Type of reset curve and Reset delay time settings. When the DT characteristic isselected, the reset timer runs until the set Reset delay time value is exceeded. When



the IDMT curves are selected, the Type of reset curve setting can be set to"Immediate", "Def time reset" or "Inverse reset". The reset curve type "Immediate"causes an immediate reset. With the reset curve type "Def time reset", the resettime depends on the Reset delay time setting. With the reset curve type "Inversereset", the reset time depends on the current during the drop-off situation. TheSTART output is deactivated when the reset timer has elapsed.









The function operates on three alternative measurement modes: "RMS", "DFT" and"Peak-to-Peak". The measurement mode is selected with the Measurement modesetting.



Table 226: Measurement modes supported by EFxPTOC stages

Measurementmode

Supported measurement modesEFLPTOC EFHPTOC EFIPTOC

RMS x x

DFT x x

Peak-to-Peak x x x



EFxPTOC supports both DT and IDMT characteristics. The user can select thetimer characteristics with the Operating curve type and Type of reset curve settings.When the DT characteristic is selected, it is only affected by the Operate delaytime and Reset delay time settings.


The following characteristics, which comply with the list in the IEC 61850-7-4specification, indicate the characteristics supported by different stages:


Operating curve type Supported byEFLPTOC EFHPTOC







x



(9) IEC Normal Inverse x x

(10) IEC Very Inverse x x

(11) IEC Inverse x




Operating curve type Supported byEFLPTOC EFHPTOC

(12) IEC Extremely Inverse x x




(17) User programmablecurve

x x

(18) RI type x

(19) RD type x

EFIPTOC supports only definite time characteristics.

For a detailed description of timers, see the General function blockfeatures section in this manual.


Reset curve type Supported by EFLPTOC EFHPTOC Note



(3) Inverse reset x x Available only for ANSIand user

programmable curves

The Type of reset curve setting does not apply to EFIPTOC or whenthe DT operation is selected. The reset is purely defined by theReset delay time setting.

4.2.1.7 Application

EFxPTOC is designed for protection and clearance of earth faults in distributionand sub-transmission networks where the neutral point is isolated or earthed via aresonance coil or through low resistance. It also applies to solidly earthed networksand earth-fault protection of different equipment connected to the power systems,such as shunt capacitor bank or shunt reactors and for backup earth-fault protectionof power transformers.



Many applications require several steps using different current start levels and timedelays. EFxPTOC consists of three different protection stages.

• Low EFLPTOC• High EFHPTOC• Instantaneous EFIPTOC

EFLPTOC contains several types of time-delay characteristics. EFHPTOC andEFIPTOC are used for fast clearance of serious earth faults.

4.2.1.8 Signals

Table 229: EFLPTOC Input signals

Name Type Default DescriptionIo SIGNAL 0 Residual current



Table 230: EFHPTOC Input signals




Table 231: EFIPTOC Input signals




Table 232: EFLPTOC Output signals


START BOOLEAN Start

Table 233: EFHPTOC Output signals


START BOOLEAN Start



Table 234: EFIPTOC Output signals


START BOOLEAN Start

4.2.1.9 Settings

Table 235: EFLPTOC Group settings









Table 236: EFLPTOC Non group settings












Parameter Values (Range) Unit Step Default DescriptionCurve parameter C 0.02...2.00 2.00 Parameter C for customer

programmable curve



Io signal Sel 1=Measured Io2=Calculated Io

1=Measured Io Selection for used Io signal

Table 237: EFHPTOC Group settings









Table 238: EFHPTOC Non group settings
















Table 239: EFIPTOC Group settings




Table 240: EFIPTOC Non group settings







Table 241: EFLPTOC Monitored data


operate time

EFLPTOC Enum 1=on2=blocked3=test4=test/blocked5=off

Status

Table 242: EFHPTOC Monitored data


operate time

EFHPTOC Enum 1=on2=blocked3=test4=test/blocked5=off

Status

Table 243: EFIPTOC Monitored data


operate time

EFIPTOC Enum 1=on2=blocked3=test4=test/blocked5=off

Status




Table 244: EFxPTOC Technical data


measured: fn ±2 Hz

EFLPTOC ±1.5% of the set value or ±0.002 x In

EFHPTOCandEFIPTOC

±1.5% of set value or ±0.002 x In(at currents in the range of 0.1…10 x In)±5.0% of the set value(at currents in the range of 10…40 x In)


EFIPTOC:IFault = 2 x set StartvalueIFault = 10 x set Startvalue

16 ms11 ms

19 ms12 ms

23 ms14 ms

EFHPTOC andEFLPTOC:IFault = 2 x set Startvalue

22 ms

24 ms

25 ms

Reset time < 40 ms





Suppression of harmonics RMS: No suppressionDFT: -50 dB at f = n x fn, where n = 2, 3, 4, 5,…Peak-to-Peak: No suppression

1) Measurement mode = default (depends on stage), current before fault = 0.0 x In, fn = 50 Hz, earth-fault current with nominal frequency injected from random phase angle, results based on statisticaldistribution of 1000 measurements



Table 245: EFIPTOC Technical revision history

Technical revision ChangeB The minimum and default values changed to 40

ms for the Operate delay time setting

C Minimum and default values changed to 20 msfor the Operate delay time settingMinimum value changed to 1.00 x In for the Startvalue setting.

D Added a setting parameter for the "Measured Io"or "Calculated Io" selection



Table 246: EFHPTOC Technical revision history



C Added a setting parameter for the "Measured Io"or "Calculated Io" selection


Table 247: EFLPTOC Technical revision history

Technical revision ChangeB The minimum and default values changed to 40

ms for the Operate delay time setting

C Start value step changed to 0.005

D Added a setting parameter for the "Measured Io"or "Calculated Io" selection

E Step value changed from 0.05 to 0.01 for theTime multiplier setting.

4.2.2 Directional earth-fault protection DEFxPDEF





Directional earth-fault protection - Lowstage

DEFLPDEF Io>-> 67N-1

Directional earth-fault protection - Highstage

DEFHPDEF Io>>-> 67N-2


A070433 V2 EN





The earth-fault function DEFxPDEF is used as directional earth-fault protection forfeeders.

The function starts and operates when the operating quantity (current) andpolarizing quantity (voltage) exceed the set limits and the angle between them isinside the set operating sector. The operate time characteristic for low stage(DEFLPDEF) and high stage (DEFHPDEF) can be selected to be either definitetime (DT) or inverse definite minimum time (IDMT).





The operation of directional earth-fault protection can be described using a modulediagram. All the modules in the diagram are explained in the next sections.

A070438 V3 EN

Figure 103: Functional module diagram. Io and Uo represent the residualcurrent and residual voltage. I2 and U2 represent the negativesequence components for current and voltage.

Level detectorThe operating quantity (residual current) can be selected with the setting Io signalSel. The selectable options are "Measured Io" and "Calculated Io" respectively. Thepolarizing quantity can be selected with the setting Pol signal Sel. The selectableoptions are "Measured Uo", "Calculated Uo" and "Neg. seq. volt". The magnitudeof the operating quantity is compared to the set Start value and the magnitude of



the polarizing quantity is compared to the set Voltage start value. If both limits areexceeded, the level detector sends an enabling signal to the timer module. Whenthe Enable voltage limit setting is set to "False", Voltage start value has no effectand the level detection is purely based on the operating quantity. If the ENA_MULTinput is active, the Start value setting is multiplied by the Start value Mult setting.

If the Enable voltage limit setting is set to "True", the magnitude ofthe polarizing quantity is checked even if the Directional mode wasset to "Non-directional" or Allow Non Dir to "True". The IED doesnot accept the Start value or Start value Mult setting if the productof these settings exceeds the Start value setting range.

Typically, the ENA_MULT input is connected to the inrush detection functionINRHPAR. In case of inrush, INRPHAR activates the ENA_MULT input, whichmultiplies Start value by the Start value Mult setting.

Directional calculationThe directional calculation module monitors the angle between the polarizingquantity and operating quantity. Depending on the Pol signal Sel setting, thepolarizing quantity can be the residual voltage (measured or calculated) or thenegative sequence voltage. When the angle is in the operation sector, the modulesends the enabling signal to the timer module.

The minimum signal level which allows the directional operation can be set withthe Min operate current and Min operate voltage settings.

If Pol signal Sel is set to "Measured Uo" or "Calculated Uo", the residual currentand residual voltage are used for directional calculation.

If Pol signal Sel is set to "Neg. seq. volt", the negative sequence current andnegative sequence voltage are used for directional calculation.

In the phasor diagrams representing the operation of DEFxPDEF, the polarity ofthe polarizing quantity (Uo or U2) is reversed, that is, the polarizing quantity in thephasor diagrams is either -Uo or -U2. Reversing is done by switching the polarityof the residual current measuring channel (see the connection diagram in theapplication manual). Similarly the polarity of the calculated Io and I2 is also switched.

For defining the operation sector, there are five modes available through theOperation mode setting.



Table 248: Operation modes

Operation mode DescriptionPhase angle The operating sectors for forward and reverse

are defined with the settings Min forward angle,Max forward angle, Min reverse angle and Maxreverse angle.

IoSin The operating sectors are defined as "forward"when |Io| x sin (ANGLE) has a positive value and"reverse" when the value is negative. ANGLE isthe angle difference between -Uo and Io.

IoCos As "IoSin" mode. Only cosine is used forcalculating the operation current.

Phase angle 80 The sector maximum values are frozen to 80degrees respectively. Only Min forward angleand Min reverse angle are settable.

Phase angle 88 The sector maximum values are frozen to 88degrees. Otherwise as "Phase angle 80" mode.

Polarizing quantity selection "Neg. seq. volt." is available only inthe "Phase angle" operation mode.

The directional operation can be selected with the Directional mode setting. Theuser can select either "Non-directional", "Forward" or "Reverse" operation. Theoperation criterion is selected with the Operation mode setting. By setting AllowNon Dir to "True", non-directional operation is allowed when the directionalinformation is invalid, that is, when the magnitude of the polarizing quantity is lessthan the value of the Min operate voltage setting.

Typically, the network rotating direction is counter-clockwise and defined as"ABC". If the network rotating direction is reversed, meaning clockwise, that is,"ACB", the equation for calculating the negative sequence voltage component needto be changed. The network rotating direction is defined with a system parameterPhase rotation. The calculation of the component is affected but the angledifference calculation remains the same. When the residual voltage is used as thepolarizing method, the network rotating direction change has no effect on thedirection calculation.

The network rotating direction is set in the IED using the parameterin the HMI menu: Configuration/System/Phase rotation.The default parameter value is "ABC".

If the Enable voltage limit setting is set to "True", the magnitude ofthe polarizing quantity is checked even if Directional mode is set to"Non-directional" or Allow Non Dir to "True".



The Characteristic angle setting is used in the "Phase angle" mode to adjust theoperation according to the method of neutral point earthing so that in an isolatednetwork the Characteristic angle (φRCA) = -90° and in a compensated networkφRCA = 0°. In addition, the characteristic angle can be changed via the controlsignal RCA_CTL. RCA_CTL affects the Characteristic angle setting.

The Correction angle setting can be used to improve selectivity when there areinaccuracies due to measurement transformers. The setting decreases the operationsector. The correction can only be used with the "IoCos" or "IoSin" modes.

The polarity of the polarizing quantity can be reversed by setting the Pol reversalto "True", which turns the polarizing quantity by 180 degrees.

For definitions of different directional earth-fault characteristics,see the Directional earth-fault characteristics section in this manual.

For definitions of different directional earth-fault characteristics,refer to general function block features information

The directional calculation module calculates several values which are presented inthe monitored data.

Table 249: Monitored data values

Monitored data values DescriptionFAULT_DIR The detected direction of fault during fault

situations, that is, when START output is active.

DIRECTION The momentary operating direction indicationoutput.

ANGLE Also called operating angle, shows the angledifference between the polarizing quantity (Uo,U2) and operating quantity (Io, I2).

ANGLE_RCA The angle difference between the operatingangle and Characteristic angle, that is,ANGLE_RCA = ANGLE – Characteristic angle.

I_OPER The current that is used for fault detection. If theOperation mode setting is "Phase angle", "Phaseangle 80" or "Phase angle 88", I_OPER is themeasured or calculated residual current. If theOperation mode setting is "IoSin", I_OPER iscalculated as follows I_OPER = Io x sin(ANGLE).If the Operation mode setting is "IoCos", I_OPERis calculated as follows I_OPER = Io xcos(ANGLE).

Monitored data values are accessible on the LHMI or through tools viacommunications.











Blocking logicThere are three operation modes in the blocking functionality. The operation modesare controlled by the BLOCK input and the global setting "Configuration/System/Blocking mode" which selects the blocking mode. The BLOCK input can be



controlled by a binary input, a horizontal communication input or an internal signalof the IED program. The influence of the BLOCK signal activation is preselectedwith the global setting Blocking mode.


4.2.2.5 Directional earth-fault principles

In many cases it is difficult to achieve selective earth-fault protection based on themagnitude of residual current only. To obtain a selective earth-fault protectionscheme, it is necessary to take the phase angle of Io into account. This is done bycomparing the phase angle of the operating and polarizing quantity.

Relay characteristic angleThe Characteristic angle setting, also known as Relay Characteristic Angle (RCA),Relay Base Angle or Maximum Torque Angle (MTA), is used in the "Phase angle"mode to turn the directional characteristic if the expected fault current angle doesnot coincide with the polarizing quantity to produce the maximum torque. That is,RCA is the angle between the maximum torque line and polarizing quantity. If thepolarizing quantity is in phase with the maximum torque line, RCA is 0 degrees.The angle is positive if the operating current lags the polarizing quantity andnegative if it leads the polarizing quantity.

Example 1

The "Phase angle" mode is selected, compensated network (φRCA = 0 deg)

=> Characteristic angle = 0 deg



GUID-829C6CEB-19F0-4730-AC98-C5528C35A297 V2 EN

Figure 104: Definition of the relay characteristic angle, RCA=0 degrees in acompensated network

Example 2

The "Phase angle" mode is selected, solidly earthed network (φRCA = +60 deg)

=> Characteristic angle = +60 deg



GUID-D72D678C-9C87-4830-BB85-FE00F5EA39C2 V2 EN

Figure 105: Definition of the relay characteristic angle, RCA=+60 degrees in asolidly earthed network

Example 3

The "Phase angle" mode is selected, isolated network (φRCA = -90 deg)

=> Characteristic angle = -90 deg



GUID-67BE307E-576A-44A9-B615-2A3B184A410D V2 EN

Figure 106: Definition of the relay characteristic angle, RCA=–90 degrees in anisolated network

Directional earth-fault protection in an isolated neutral networkIn isolated networks, there is no intentional connection between the system neutralpoint and earth. The only connection is through the phase-to-earth capacitances(C0) of phases and leakage resistances (R0). This means that the residual current ismainly capacitive and has a phase shift of –90 degrees compared to the polarizingvoltage. Consequently, the relay characteristic angle (RCA) should be set to -90degrees and the operation criteria to "IoSin" or "Phase angle". The width of theoperating sector in the phase angle criteria can be selected with the settings Minforward angle, Max forward angle, Min reverse angle or Max reverse angle.Figure 107 illustrates a simplified equivalent circuit for an unearthed network withan earth fault in phase C.

For definitions of different directional earth-fault characteristics,see Directional earth-fault principles .



A070441 V1 EN

Figure 107: Earth-fault situation in an isolated network

Directional earth-fault protection in a compensated networkIn compensated networks, the capacitive fault current and the inductive resonancecoil current compensate each other. The protection cannot be based on the reactivecurrent measurement, since the current of the compensation coil would disturb theoperation of the IEDs. In this case, the selectivity is based on the measurement ofthe active current component. The magnitude of this component is often small andmust be increased by means of a parallel resistor in the compensation equipment.When measuring the resistive part of the residual current, the relay characteristicangle (RCA) should be set to 0 degrees and the operation criteria to "IoSin" or"Phase angle". Figure 108 illustrates a simplified equivalent circuit for acompensated network with an earth fault in phase C.

A070444 V2 EN

Figure 108: Earth-fault situation in a compensated network

The Petersen coil or the earthing resistor may be temporarily out of operation. Tokeep the protection scheme selective, it is necessary to update the characteristicangle setting accordingly. This can be done with an auxiliary input in the relaywhich receives a signal from an auxiliary switch of the disconnector of the Petersen



coil in compensated networks. As a result the characteristic angle is setautomatically to suit the earthing method used. The RCA_CTL input can be used tochange the operation criteria as described in Table 250 and Table 251.

Table 250: Relay characteristic angle control in Iosin(φ) and Iocos(φ) operation criteria

Operation mode setting: RCA_CTL = FALSE RCA_CTL = TRUEIosin Actual operation mode: Iosin Actual operation mode: Iocos

Iocos Actual operation mode: Iocos Actual operation mode: Iosin

Table 251: Characteristic angle control in phase angle operation mode

Characteristicangle setting

RCA_CTL = FALSE RCA_CTL = TRUE

-90° φRCA = -90° φRCA = 0°

0° φRCA = 0° φRCA = -90°

Use of the extended phase angle characteristicThe traditional method of adapting the directional earth-fault protection function tothe prevailing neutral earthing conditions is done with the Characteristic anglesetting. In an unearthed network, Characteristic angle is set to -90 degrees and in acompensated network Characteristic angle is set to 0 degrees. In case the earthingmethod of the network is temporarily changed from compensated to unearthed dueto the disconnection of the arc suppression coil, the Characteristic angle settingshould be modified correspondingly. This can be done using the setting groups orthe RCA_CTL input. Alternatively, the operating sector of the directional earth-fault protection function can be extended to cover the operating sectors of bothneutral earthing principles. Such characteristic is valid for both unearthed andcompensated network and does not require any modification in case the neutralearthing changes temporarily from the unearthed to compensated network or viceversa.

The extended phase angle characteristic is created by entering a value of over 90degrees for the Min forward angle setting; a typical value is 170 degrees (Minreverse angle in case Directional mode is set to "Reverse"). The Max forwardangle setting should be set to cover the possible measurement inaccuracies ofcurrent and voltage transformers; a typical value is 80 degrees (Max reverse anglein case Directional mode is set to "Reverse").



A070443 V3 EN

Figure 109: Extended operation area in directional earth-fault protection



Table 252: Measurement modes supported by DEFxPDEF stages

Measurement mode Supported measurement modesDEFLPDEF DEFHPDEF

RMS x x

DFT x x

Peak-to-Peak x x





DEFxPDEF supports both DT and IDMT characteristics. The user can select thetimer characteristics with the Operating curve type setting.


The following characteristics, which comply with the list in the IEC 61850-7-4specification, indicate the characteristics supported by different stages.


Operating curve type Supported byDEFLPDEF DEFHPDEF







x



(9) IEC Normal Inverse x

(10) IEC Very Inverse x

(11) IEC Inverse x

(12) IEC Extremely Inverse x




(17) User programmablecurve

x x

(18) RI type x

(19) RD type x

For a detailed description of the timers, see the General functionblock features section in this manual.




Reset curve type Supported by DEFLPDEF DEFHPDEF Note



(3) Inverse reset x x Available only for ANSIand user

programmable curves

4.2.2.8 Directional earth-fault characteristics

Phase angle characteristicThe operation criterion phase angle is selected with the Operation mode settingusing the value "Phase angle".

When the phase angle criterion is used, the function indicates with theDIRECTION output whether the operating quantity is within the forward orreverse operation sector or within the non-directional sector.

The forward and reverse sectors are defined separately. The forward operation areais limited with the Min forward angle and Max forward angle settings. The reverseoperation area is limited with the Min reverse angle and Max reverse angle settings.

The sector limits are always given as positive degree values.

In the forward operation area, the Max forward angle setting gives the clockwisesector and the Min forward angle setting correspondingly the counterclockwisesector, measured from the Characteristic angle setting.

In the reverse operation area, the Max reverse angle setting gives the clockwisesector and the Min reverse angle setting correspondingly the counterclockwisesector, measured from the complement of the Characteristic angle setting (180degrees phase shift) .

The relay characteristic angle (RCA) is set to positive if the operating current lagsthe polarizing quantity. It is set to negative if it leads the polarizing quantity.



GUID-92004AD5-05AA-4306-9574-9ED8D51524B4 V2 EN

Figure 110: Configurable operating sectors in phase angle characteristic

Table 255: Momentary operating direction

Fault direction The value for DIRECTIONAngle between the polarizing and operatingquantity is not in any of the defined sectors.

0 = unknown

Angle between the polarizing and operatingquantity is in the forward sector.

1= forward

Angle between the polarizing and operatingquantity is in the reverse sector.

2 = backward

Angle between the polarizing and operatingquantity is in both the forward and the reversesectors, that is, the sectors are overlapping.

3 = both

If the Allow Non Dir setting is "False", the directional operation (forward, reverse)is not allowed when the measured polarizing or operating quantities are invalid,that is, their magnitude is below the set minimum values. The minimum values canbe defined with the settings Min operate current and Min operate voltage. In caseof low magnitudes, the FAULT_DIR and DIRECTION outputs are set to 0 =unknown, except when the Allow non dir setting is "True". In that case, the



function is allowed to operate in the directional mode as non-directional, since thedirectional information is invalid.

Iosin(φ) and Iocos(φ) criteriaA more modern approach to directional protection is the active or reactive currentmeasurement. The operating characteristic of the directional operation depends onthe earthing principle of the network. The Iosin(φ) characteristics is used in anisolated network, measuring the reactive component of the fault current caused bythe earth capacitance. The Iocos(φ) characteristics is used in a compensatednetwork, measuring the active component of the fault current.

The operation criteria Iosin(φ) and Iocos(φ) are selected with the Operation modesetting using the values "IoSin" or "IoCos" respectively.

The angle correction setting can be used to improve selectivity. The settingdecreases the operation sector. The correction can only be used with the Iosin(φ) orIocos(φ) criterion. The RCA_CTL input is used to change the Io characteristic:

Table 256: Relay characteristic angle control in the IoSin and IoCos operation criteria

Operation mode: RCA_CTL = "False" RCA_CTL = "True"IoSin Actual operation criterion:

Iosin(φ)Actual operation criterion:Iocos(φ)

IoCos Actual operation criterion:Iocos(φ)

Actual operation criterion:Iosin(φ)

When the Iosin(φ) or Iocos(φ) criterion is used, the component indicates a forward-or reverse-type fault through the FAULT_DIR and DIRECTION outputs, in which1 equals a forward fault and 2 equals a reverse fault. Directional operation is notallowed (the Allow non dir setting is "False") when the measured polarizing oroperating quantities are not valid, that is, when their magnitude is below the setminimum values. The minimum values can be defined with the Min operatecurrent and Min operate voltage settings. In case of low magnitude, theFAULT_DIR and DIRECTION outputs are set to 0 = unknown, except when theAllow non dir setting is "True". In that case, the function is allowed to operate inthe directional mode as non-directional, since the directional information is invalid.

The calculated Iosin(φ) or Iocos(φ) current used in direction determination can beread through the I_OPER monitored data. The value can be passed directly to adecisive element, which provides the final start and operate signals.

The I_OPER monitored data gives an absolute value of thecalculated current.

The following examples show the characteristics of the different operation criteria:

Example 1.



Iosin(φ) criterion selected, forward-type fault

=> FAULT_DIR = 1

GUID-560EFC3C-34BF-4852-BF8C-E3A2A7750275 V2 EN

Figure 111: Operating characteristic Iosin(φ) in forward fault

The operating sector is limited by Angle correction, that is, the operating sector is180 degrees - 2*(Angle correction).

Example 2.

Iosin(φ) criterion selected, reverse-type fault

=> FAULT_DIR = 2



GUID-10A890BE-8C81-45B2-9299-77DD764171E1 V2 EN

Figure 112: Operating characteristic Iosin(φ) in reverse fault

Example 3.

Iocos(φ) criterion selected, forward-type fault

=> FAULT_DIR = 1

GUID-11E40C1F-6245-4532-9199-2E2F1D9B45E4 V2 EN

Figure 113: Operating characteristic Iocos(φ) in forward fault

Example 4.



Iocos(φ) criterion selected, reverse-type fault

=> FAULT_DIR = 2

GUID-54ACB854-F11D-4AF2-8BDB-69E5F6C13EF1 V2 EN

Figure 114: Operating characteristic Iocos(φ) in reverse fault

Phase angle 80The operation criterion phase angle 80 is selected with the Operation mode settingby using the value "Phase angle 80".

Phase angle 80 implements the same functionality as the phase angle but with thefollowing differences:

• The Max forward angle and Max reverse angle settings cannot be set but theyhave a fixed value of 80 degrees

• The sector limits of the fixed sectors are rounded.

The sector rounding is used for cancelling the CT measurement errors at lowcurrent amplitudes. When the current amplitude falls below three percent of thenominal current, the sector is reduced to 70 degrees at the fixed sector side. Thismakes the protection more selective, which means that the phase anglemeasurement errors do not cause faulty operation.

There is no sector rounding on the other side of the sector.



GUID-EFC9438D-9169-4733-9BE9-6B343F37001A V2 EN

Figure 115: Operating characteristic for phase angle 80

2

3

4

6

7

8

9

10

Io / % of In

0 90453015 7560-90 -45 -30 -15-75 -60

Min forward angle

1

80 deg

70 deg

Operating zone

Non-operating

zone

3% of In

1% of In

GUID-49D23ADF-4DA0-4F7A-8020-757F32928E60 V2 EN

Figure 116: Phase angle 80 amplitude (Directional mode = Forward)

Phase angle 88The operation criterion phase angle 88 is selected with the Operation mode settingusing the value "Phase angle 88".



Phase angle 88 implements the same functionality as the phase angle but with thefollowing differences:

• The Max forward angle and Max reverse angle settings cannot be set but theyhave a fixed value of 88 degrees

• The sector limits of the fixed sectors are rounded.

Sector rounding in the phase angle 88 consists of three parts:

• If the current amplitude is between 1...20 percent of the nominal current, thesector limit increases linearly from 73 degrees to 85 degrees

• If the current amplitude is between 20...100 percent of the nominal current, thesector limit increases linearly from 85 degrees to 88 degrees

• If the current amplitude is more than 100 percent of the nominal current, thesector limit is 88 degrees.

There is no sector rounding on the other side of the sector.

GUID-0F0560B7-943E-4CED-A4B8-A561BAE08956 V2 EN

Figure 117: Operating characteristic for phase angle 88



20

30

40

50

70

80

90

100

Io / % of In

0 90453015 7560-90 -45 -30 -15-75 -60

Min forward angle

10

88 deg

85 deg

73 deg

100% of In

20% of In

1% of In

GUID-F9F1619D-E1B5-4650-A5CB-B62A7F6B0A90 V2 EN

Figure 118: Phase angle 88 amplitude (Directional mode = Forward)

4.2.2.9 Application

The directional earth-fault protection DEFxPDEF is designed for protection andclearance of earth faults and for earth-fault protection of different equipmentconnected to the power systems, such as shunt capacitor banks or shunt reactors,and for backup earth-fault protection of power transformers.

Many applications require several steps using different current start levels and timedelays. DEFxPDEF consists of two different stages.

• Low DEFLPDEF• High DEFHPDEF

DEFLPDEF contains several types of time delay characteristics. DEFHPDEF isused for fast clearance of serious earth faults.

The protection can be based on the phase angle criterion with extended operatingsector. It can also be based on measuring either the reactive part Iosin(φ) or theactive part Iocos(φ) of the residual current. In isolated networks or in networkswith high impedance earthing, the phase-to-earth fault current is significantlysmaller than the short-circuit currents. In addition, the magnitude of the faultcurrent is almost independent of the fault location in the network.

The function uses the residual current components Iocos(φ) or Iosin(φ) accordingto the earthing method, where φ is the angle between the residual current and thereference residual voltage (-Uo). In compensated networks, the phase anglecriterion with extended operating sector can also be used. When the relaycharacteristic angle RCA is 0 degrees, the negative quadrant of the operation sectorcan be extended with the Min forward angle setting. The operation sector can beset between 0 and -180 degrees, so that the total operation sector is from +90 to-180 degrees. In other words, the sector can be up to 270 degrees wide. This allows



the protection settings to stay the same when the resonance coil is disconnectedfrom between the neutral point and earth.

System neutral earthing is meant to protect personnel and equipment and to reduceinterference for example in telecommunication systems. The neutral earthing setschallenges for protection systems, especially for earth-fault protection.

In isolated networks, there is no intentional connection between the system neutralpoint and earth. The only connection is through the line-to-earth capacitances (C0)of phases and leakage resistances (R0). This means that the residual current ismainly capacitive and has –90 degrees phase shift compared to the residual voltage(-Uo). The characteristic angle is -90 degrees.

In resonance-earthed networks, the capacitive fault current and the inductiveresonance coil current compensate each other. The protection cannot be based onthe reactive current measurement, since the current of the compensation coil woulddisturb the operation of the relays. In this case, the selectivity is based on themeasurement of the active current component. This means that the residual currentis mainly resistive and has zero phase shift compared to the residual voltage (-Uo)and the characteristic angle is 0 degrees. Often the magnitude of this component issmall, and must be increased by means of a parallel resistor in the compensationequipment.

In networks where the neutral point is earthed through low resistance, thecharacteristic angle is also 0 degrees (for phase angle). Alternatively, Iocos(φ)operation can be used.

In solidly earthed networks, the Characteristic angle is typically set to +60 degreesfor the phase angle. Alternatively, Iosin(φ) operation can be used with a reversalpolarizing quantity. The polarizing quantity can be rotated 180 degrees by settingthe Pol reversal parameter to "True" or by switching the polarity of the residualvoltage measurement wires. Although the Iosin(φ) operation can be used in solidlyearthed networks, the phase angle is recommended.

Connection of measuring transformers in directional earth faultapplicationsThe residual current Io can be measured with a core balance current transformer orthe residual connection of the phase current signals. If the neutral of the network iseither isolated or earthed with high impedance, a core balance current transformeris recommended to be used in earth-fault protection. To ensure sufficient accuracyof residual current measurements and consequently the selectivity of the scheme,the core balance current transformers should have a transformation ratio of at least70:1. Lower transformation ratios such as 50:1 or 50:5 are not recommended.

Attention should be paid to make sure the measuring transformers are connectedcorrectly so that DEFxPDEF is able to detect the fault current direction withoutfailure. As directional earth fault uses residual current and residual voltage (-Uo),the poles of the measuring transformers must match each other and also the faultcurrent direction. Also the earthing of the cable sheath must be taken into notice



when using core balance current transformers. The following figure describes howmeasuring transformers can be connected to the IED.

A070697 V2 EN

Figure 119: Connection of measuring transformers

4.2.2.10 Signals

Table 257: DEFLPDEF Input signals


Uo SIGNAL 0 Residual voltage



RCA_CTL BOOLEAN 0=False Relay characteristic angle control

Table 258: DEFHPDEF Input signals








Table 259: DEFLPDEF Output signals


START BOOLEAN Start

Table 260: DEFHPDEF Output signals


START BOOLEAN Start

4.2.2.11 Settings

Table 261: DEFLPDEF Group settings











Operation mode 1=Phase angle2=IoSin3=IoCos4=Phase angle 805=Phase angle 88

1=Phase angle Operation criteria

Characteristic angle -179...180 deg 1 -90 Characteristic angle





Parameter Values (Range) Unit Step Default DescriptionMax reverse angle 0...180 deg 1 80 Maximum phase angle in reverse

direction



Voltage start value 0.010...1.000 xUn 0.001 0.010 Voltage start value

Enable voltage limit 0=False1=True

1=True Enable voltage limit

Table 262: DEFLPDEF Non group settings











Correction angle 0.0...10.0 deg 0.1 0.0 Angle correction

Pol reversal 0=False1=True

0=False Rotate polarizing quantity








Pol signal Sel 1=Measured Uo2=Calculated Uo3=Neg. seq. volt.

1=Measured Uo Selection for used polarization signal



Table 263: DEFHPDEF Group settings






Operating curve type 1=ANSI Ext. inv.3=ANSI Norm. inv.5=ANSI Def. Time15=IEC Def. Time17=Programmable





Operation mode 1=Phase angle2=IoSin3=IoCos4=Phase angle 805=Phase angle 88

1=Phase angle Operation criteria






Voltage start value 0.010...1.000 xUn 0.001 0.010 Voltage start value

Enable voltage limit 0=False1=True

1=True Enable voltage limit

Table 264: DEFHPDEF Non group settings















Parameter Values (Range) Unit Step Default DescriptionPol reversal 0=False

1=True 0=False Rotate polarizing quantity








Pol signal Sel 1=Measured Uo2=Calculated Uo3=Neg. seq. volt.



Table 265: DEFLPDEF Monitored data

Name Type Values (Range) Unit DescriptionFAULT_DIR Enum 0=unknown






ANGLE_RCA FLOAT32 -180.00...180.00 deg Angle between operatingangle and characteristicangle

ANGLE FLOAT32 -180.00...180.00 deg Angle betweenpolarizing and operatingquantity

I_OPER FLOAT32 0.00...40.00 Calculated operatingcurrent

DEFLPDEF Enum 1=on2=blocked3=test4=test/blocked5=off

Status



Table 266: DEFHPDEF Monitored data









I_OPER FLOAT32 0.00...40.00 Calculated operatingcurrent

DEFHPDEF Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 267: DEFxPDEF Technical data


measured: fn ±2 Hz

DEFLPDEF Current:±1.5% of the set value or ±0.002 x InVoltage±1.5% of the set value or ±0.002 x UnPhase angle:±2°

DEFHPDEF Current:±1.5% of the set value or ±0.002 x In(at currents in the range of 0.1…10 x In)±5.0% of the set value(at currents in the range of 10…40 x In)Voltage:±1.5% of the set value or ±0.002 x UnPhase angle:±2°




Characteristic ValueStart time 1)2) Minimum Typical Maximum

DEFHPDEFIFault = 2 x set Startvalue

42 ms

44 ms

46 ms

DEFLPDEFIFault = 2 x set Startvalue

61 ms 64 ms 66 ms

Reset time < 40 ms





Suppression of harmonics RMS: No suppressionDFT: -50 dB at f = n x fn, where n = 2, 3, 4, 5,…Peak-to-Peak: No suppression

1) Measurement mode = default (depends on stage), current before fault = 0.0 x In, fn = 50 Hz, earth-fault current with nominal frequency injected from random phase angle, results based on statisticaldistribution of 1000 measurements



Table 268: DEFHPDEF Technical revision history

Technical revision ChangeB Maximum value changed to 180 deg for the Max

forward angle setting

C Added a setting parameter for the "Measured Io"or "Calculated Io" selection and settingparameter for the "Measured Uo", "CalculatedUo" or "Neg. seq. volt." selection for polarization.Operate delay time and Minimum operate timechanged from 60 ms to 40 ms. The sectordefault setting values are changed from 88degrees to 80 degrees.




Table 269: DEFLPDEF Technical revision history

Technical revision ChangeB Maximum value changed to 180 deg for the Max

forward angle setting.Start value step changed to 0.005

C Added a setting parameter for the "Measured Io"or "Calculated Io" selection and settingparameter for the "Measured Uo", "CalculatedUo" or "Neg. seq. volt." selection for polarization.The sector default setting values are changedfrom 88 degrees to 80 degrees.


4.2.3 Transient/intermittent earth-fault protection INTRPTEF





Transient/intermittent earth-faultprotection

INTRPTEF Io> ->IEF 67NIEF


A070663 V2 EN



The transient/intermittent measuring earth-fault protection INTRPTEF is a functiondesigned for the protection and clearance of permanent and intermittent earth faultsin distribution and sub-transmission networks. Fault detection is done from theresidual current and residual voltage signals by monitoring the transients.

The operating time characteristics are according to definite time (DT).






The operation of transient/intermittent earth-fault protection can be described witha module diagram. All the modules in the diagram are explained in the next sections.

BLK_EF

OPERATEIo

Uo

BLOCK

START

Timer 2

tTimer 1

Transient detector

Faultindication

logic

Leveldetector

Blockinglogic

A070661 V4 EN

Figure 121: Functional module diagram. Io and Uo stand for residual currentand residual voltage

Level detectorThe Level detector module compares the measured residual voltage to the setVoltage start value. If the measured value exceeds the set Voltage start value, themodule reports the exceeding of the value to the Fault indication logic.

Transient detectorThe Transient detector module is used for detecting transients in the residualcurrent and residual voltage signals.

The sensitivity of the transient detection can be adjusted with the Min operatecurrent setting. This setting should be set based on the value of the parallel resistorof the coil, with security margin. For example, if the resistive current of the parallelresistor is 10 A, then a value of 0.7*10 A = 7 A could be used. The same setting isalso applicable in case the coil is disconnected and the network becomes unearthed.Generally, a smaller value should be used and it must never exceed the value of theparallel resistor in order to allow operation of the faulted feeder.

Fault indication logicDepending on the set Operation mode, INTRPTEF has two independent modes fordetecting earth faults. The "Transient EF" mode is intended to detect all kinds of



earth faults. The "Intermittent EF" mode is dedicated for detecting intermittentearth faults in cable networks.

Traditional earth fault protection should always be used in parallelwith the INTRPTEF function.

The Fault indication logic module determines the direction of the fault. WhenDirectional mode setting "Forward" is used, the protection operates when the faultis in the protected feeder. When Directional mode setting "Reverse" is used, theprotection operates when the fault is outside the protected feeder (in thebackground network). If the direction has no importance, the value "Non-directional" can be selected. The detected fault direction (FAULT_DIR) isavailable in the monitored data view.

In the "Transient EF" mode, when the start transient of the fault is detected and theUo level exceeds the set Voltage start value, Timer 1 is activated. Timer 1 is keptactivated until the Uo level exceeds the set value or in case of a drop-off, the drop-off duration is shorter than the set Reset delay time.

In the "Intermittent EF" mode, the Timer 1 is activated from the first detectedtransient. When a required number of intermittent earth-fault transients set with thePeak counter limit setting are detected without the function being reset (depends onthe drop-off time set with the Reset delay time setting), the START output isactivated. The Timer 1 is kept activated as long as transients are occurring duringthe drop-off time Reset delay time.

Timer 1The time characteristic is according to DT. In the "Transient EF" mode, theOPERATE output is activated after Operate delay time if the residual voltageexceeds the set Voltage start value.

In the "Intermittent EF" mode the OPERATE output is activated when thefollowing conditions are fulfilled:

• the number of transients that have been detected exceeds the Peak counterlimit setting

• the timer has reached the time set with the Operate delay time• and one additional transient is detected during the drop-off cycle

The timer calculates the start duration value START_DUR which indicates thepercentage ratio of the start situation and the set operating time. The value isavailable in the monitored data view.

Timer 2If the function is used in the directional mode and an opposite direction transient isdetected, the BLK_EF output is activated for the fixed delay time of 25 ms. If theSTART output is activated when the BLK_EF output is active, the BLK_EF outputis deactivated.



Blocking logicThere are three operation modes in the blocking functionality. The operation modesare controlled by the BLOCK input and the global setting Configuration/System/Blocking mode which selects the blocking mode. The BLOCK input can becontrolled by a binary input, a horizontal communication input or an internal signalof the IED program. The influence of the BLOCK signal activation is preselectedwith the global setting Blocking mode.

The Blocking mode setting has three blocking methods. In the Freeze timers mode,the operation timer is frozen to the prevailing value. In the Block all mode, thewhole function is blocked and the timers are reset. In the Block OPERATE outputmode, the function operates normally but the OPERATE output is not activated.

4.2.3.5 Application

INTRPTEF is an earth-fault function dedicated to operate in intermittent andpermanent earth faults occurring in distribution and sub-transmission networks.Fault detection is done from the residual current and residual voltage signals bymonitoring the transients with predefined criteria. As the function has a dedicatedpurpose for the fault types, fast detection and clearance of the faults can be achieved.

Intermittent earth faultIntermittent earth fault is a special type of fault that is encountered especially incompensated networks with underground cables. A typical reason for this type offault is the deterioration of cable insulation either due to mechanical stress or dueto insulation material aging process where water or moisture gradually penetratesthe cable insulation. This eventually reduces the voltage withstand of theinsulation, leading to a series of cable insulation breakdowns. The fault is initiatedas the phase-to-earth voltage exceeds the reduced insulation level of the fault pointand mostly extinguishes itself as the fault current drops to zero for the first time, asshown in Figure 122. As a result, very short transients, that is, rapid changes in theform of spikes in residual current (Io) and in residual voltage (Uo), can berepeatedly measured. Typically, the fault resistance in case of an intermittent earthfault is only a few ohms.



Residual current Io and residual voltage Uo

FEEDER FEEDER MEAS

Iov

FaultPoint

KRe

-0.3

-0.2

-0.1

Res

idua

l Cur

rent

(kA

)R

esid

ual V

olta

ge x

10

2(k

V)

INCOMER

COMP. COIL

IojUo

KRe

0

0.1

Ioj(FaultyFeeder)

Iov(HealthyFeeder)

UoPulse width400 - 800 s

Pulse interval5 - 300 ms

Peak value~0.1 ... 5 kA

UtresUtres

Ictot

Rf

GUID-415078AD-21B3-4103-9622-712BB88F274A V2 EN

Figure 122: Typical intermittent earth-fault characteristics

Earth-fault transientsIn general, earth faults generate transients in currents and voltages. There areseveral factors that affect the magnitude and frequency of these transients, such asthe fault moment on the voltage wave, fault location, fault resistance and theparameters of the feeders and the supplying transformers. In the fault initiation, thevoltage of the faulty phase decreases and the corresponding capacitance isdischarged to earth (→ discharge transients). At the same time, the voltages of thehealthy phases increase and the related capacitances are charged (→ charge transient).

If the fault is permanent (non-transient) in nature, only the initial fault transient incurrent and voltage can be measured, whereas the intermittent fault createsrepetitive transients.



GUID-CC4ADDEA-EE11-4011-B184-F873473EBA9F V1 EN

Figure 123: Example of earth-fault transients, including discharge and chargetransient components, when a permanent fault occurs in a 20 kVnetwork in phase C

4.2.3.6 Signals

Table 270: INTRPTEF Input signals




Table 271: INTRPTEF Output signals


START BOOLEAN Start

BLK_EF BOOLEAN Block signal for EF to indicate opposite directionpeaks

4.2.3.7 Settings

Table 272: INTRPTEF Group settings

Parameter Values (Range) Unit Step Default DescriptionDirectional mode 1=Non-directional

2=Forward3=Reverse



Voltage start value 0.10...0.50 xUn 0.01 0.20 Voltage start value for transient EF



Table 273: INTRPTEF Non group settings



Operation mode 1=Intermittent EF2=Transient EF

1=Intermittent EF Operation criteria


Peak counter limit 2...20 2 Min requirement for peak counter beforestart in IEF mode

Min operate current 0.01...1.00 xIn 0.01 0.01 Minimum operating current for transientdetector


Table 274: INTRPTEF Monitored data





INTRPTEF Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 275: INTRPTEF Technical data

Characteristic ValueOperation accuracy (Uo criteria with transientprotection)

Depending on the frequency of the currentmeasured: fn ±2 Hz

±1.5% of the set value or ±0.002 x Uo

Operate time accuracy ±1.0% of the set value or ±20 ms

Suppression of harmonics DFT: -50 dB at f = n x fn, where n = 2, 3, 4, 5




Table 276: INTRPTEF Technical revision history



C The Minimum operate current setting is added.Correction in IEC61850 mapping: DO BlkEFrenamed to InhEF. Minimum value changed from0.01 to 0.10 (default changed from 0.01 to 0.20)for the Voltage start value setting. Minimumvalue changed from 0 ms to 40 ms for the Resetdelay time setting.

4.2.4 Admittance-based earth-fault protection EFPADM


Functional description IEC 61850identification



Admittance-based earth-fault protection EFPADM Yo>-> 21YN


GUID-70A9F388-3588-4550-A291-CB0E74E95F6E V1 EN



The admittance-based earth-fault protection function EFPADM provides aselective earth-fault protection function for high-resistance earthed, unearthed andcompensated networks. It can be applied for the protection of overhead lines aswell as with underground cables. It can be used as an alternative solution totraditional residual current-based earth-fault protection functions, such as the IoCosmode in DEFxPDEF. Main advantages of EFPADM include a versatileapplicability, good sensitivity and easy setting principles.

EFPADM is based on evaluating the neutral admittance of the network, that is, thequotient:



Yo Io Uo= −/

GUID-F8BBC6A4-47BB-4FCB-A2E0-87FD46073AAF V1 EN (Equation 14)

The measured admittance is compared to the admittance characteristic boundariesin the admittance plane. The supported characteristics include overadmittance,oversusceptance, overconductance or any combination of the three. Thedirectionality of the oversusceptance and overconductance criteria can be definedas forward, reverse or non-directional, and the boundary lines can be tilted ifrequired by the application. This allows the optimization of the shape of theadmittance characteristics for any given application.

EFPADM supports two calculation algorithms for admittance. The admittancecalculation can be set to include or exclude the prefault zero-sequence values of Ioand Uo. Furthermore, the calculated admittance is recorded at the time of the tripand it can be monitored for post-fault analysis purposes.

To ensure the security of the protection, the admittance calculation is supervised bya residual overvoltage condition which releases the admittance protection during afault condition. Alternatively, the release signal can be provided by an externalbinary signal.




The operation of the admittance-based earth-fault protection can be described usinga module diagram. All the modules in the diagram are explained in the next sections.

OPERATENeutral admittance calculation

BLOCK

START

Io

Uo

RELEASE

t

Timer

Operation characteristics

Blockinglogic

GUID-BAD34871-A440-433D-8101-022E1E245A0D V1 EN


Neutral admittance calculationThe function can operate on the measured or calculated residual quantities. Theresidual current can be selected with the Io signal Sel setting. The selectableoptions are "Measured Io" and "Calculated Io". Respectively, the residual voltagecan be selected with the Uo signal Sel setting. The selectable options are"Measured Uo" and "Calculated Uo".



When the residual voltage exceeds the set threshold Voltage start value, an earthfault is detected and the neutral admittance calculation is released.

To ensure a sufficient accuracy for the Io and Uo measurements, it is required thatthe residual voltage exceeds the value set by Min operate voltage. If the admittancecalculation mode is "Delta", the minimum change in the residual voltage due to afault must be 0.01 xUn to enable the operation. Similarly, the residual current mustexceed the value set by Min operate current.

The polarity of the polarizing quantity Uo can be changed, that is,rotated by 180 degrees, by setting the Pol reversal parameter to"True" or by switching the polarity of the residual voltagemeasurement wires.

As an alternative for the internal residual overvoltage-based start condition, theneutral admittance protection can also be externally released by utilizing theRELEASE input.

When Admittance Clc mode is set to "Delta", the external logic used must be ableto give RELEASE in less than 0.1 s. Otherwise the collected pre-fault values areoverwritten with fault time values. If it is slower, Admittance Clc mode must be setto “Normal”.

Neutral admittance is calculated as the quotient between the residual current andresidual voltage (polarity reversed) fundamental frequency phasors. TheAdmittance Clc mode setting defines the calculation mode:

Admittance Clc mode = "Normal"

YoIo

Uo

fault

fault

=−

GUID-B1E03EA1-E958-43F3-8A28-2D268138DE36 V1 EN (Equation 15)

Admittance Clc mode = "Delta"

YoIo Io

Uo Uo

Io

Uo

fault prefault

fault prefault

=−

− −=

−( )

∆

∆

GUID-B0611FF1-46FD-4E81-A11D-4721F0AF7BF8 V1 EN (Equation 16)

Yo Calculated neutral admittance [Siemens]

Iofault Residual current during the fault [Amperes]

Uofault Residual voltage during the fault [Volts]

Ioprefault Prefault residual current [Amperes]

Uoprefault Prefault residual voltage [Volts]

ΔIo Change in the residual current due to fault [Amperes]

ΔUo Change in the residual voltage due to fault [Volts]



Traditionally, admittance calculation is done with the calculation mode "Normal",that is, with the current and voltage values directly measured during the fault. Asan alternative, by selecting the calculation mode "Delta", the prefault zero-sequence asymmetry of the network can be removed from the admittancecalculation. Theoretically, this makes the admittance calculation totally immune tofault resistance, that is, the estimated admittance value is not affected by faultresistance. Utilization of the change in Uo and Io due to a fault in the admittancecalculation also mitigates the effects of the VT and CT measurement errors, thusimproving the measuring accuracy, the sensitivity and the selectivity of the protection.

Calculation mode "Delta" is recommended in case a high sensitivityof the protection is required, if the network has a high degree ofasymmetry during the healthy state or if the residual currentmeasurement is based on sum connection, that is, the Holmgrenconnection.

Neutral admittance calculation produces the following values during forward andreverse faults:

Fault in reverse direction, that is, outside the protected feeder:

Yo YFdtot

= −

GUID-B6E3F720-1F9F-4C11-A5DC-722838E8CCDA V1 EN (Equation 17)

≈ − ⋅jI

U

eFd

ph

GUID-19AA418B-9A0A-4CEE-8772-0CD3F595E63F V1 EN (Equation 18)

YFdtot Sum of the phase-to-earth admittances (YFdA, YFdB, YFdC) of the protected feeder

IeFd Magnitude of the earth-fault current of the protected feeder when the fault resistance iszero ohm

Uph Magnitude of the nominal phase-to-earth voltage of the system

Equation 17 shows that in case of outside faults, the measured admittance equalsthe admittance of the protected feeder with a negative sign. The measuredadmittance is dominantly reactive; the small resistive part of the measuredadmittance is due to the leakage losses of the feeder. Theoretically, the measuredadmittance is located in the third quadrant in the admittance plane close to theim(Yo) axis, see Figure 126.

The result of Equation 17 is valid regardless of the neutral earthingmethod. In compensated networks the compensation degree doesnot affect the result. This enables a straightforward setting principlefor the neutral admittance protection: admittance characteristic isset to cover the value Yo = –YFdtot with a suitable margin.



Due to inaccuracies in voltage and current measurement, the smallreal part of the calculated neutral admittance may appear aspositive, which brings the measured admittance in the fourthquadrant in the admittance plane. This should be considered whensetting the admittance characteristic.

~

~

~

A B C

Uo

EA

EB

EC

Io

Reverse Fault

YFd

LccRcc

YBg

IeFd(IeTot - IeFd)

Rn

Protected feeder

Background network

Im(Yo)

Re(Yo)Reverse fault:

Yo ≈ -j*IeFd/Uph

GUID-B852BF65-9C03-49F2-8FA9-E958EB37FF13 V1 EN

Figure 126: Admittance calculation during a reverse fault

RCC Resistance of the parallel resistor

LCC Inductance of the compensation coil

Rn Resistance of the neutral earthing resistor

YFd Phase-to-earth admittance of the protected feeder

YBg Phase-to-earth admittance of the background network



For example, in a 15 kV compensated network with the magnitude of the earth-fault current in the protected feeder being 10 A (Rf = 0 ohm), the theoretical valuefor the measured admittance during an earth fault in the reverse direction, that is,outside the protected feeder, can be calculated:

Yo jI

Uj

A

kVjeFd

ph

≈ − ⋅ = − ⋅ = − ⋅10

15 31 15. milliSiemens

GUID-E2A45F20-9821-436E-94F1-F0BFCB78A1E3 V1 EN (Equation 19)

The result is valid regardless of the neutral earthing method.

In this case, the resistive part of the measured admittance is due to leakage lossesof the protected feeder. As they are typically very small, the resistive part is closeto zero. Due to inaccuracies in the voltage and current measurement, the small realpart of the apparent neutral admittance may appear positive. This should beconsidered in the setting of the admittance characteristic.

Fault in the forward direction, that is, inside the protected feeder:

Unearthed network:

Yo Y Bgtot=

GUID-5F1D2145-3C0F-4F8F-9E17-5B88C1822566 V1 EN (Equation 20)

≈ ⋅−

jI I

U

eTot eFd

ph

GUID-0B7C9BA9-B41B-4825-9C1B-F8F36640B693 V1 EN (Equation 21)

Compensated network:

Yo Y YBgtot CC= +

GUID-F3810944-D0E1-4C9A-A99B-8409F4D3CF05 V1 EN (Equation 22)

≈+ ⋅ ⋅ −( ) −( )I j I K I

U

Rcc eTot eFd

ph

1

GUID-208EA80C-62B6-46E0-8A5B-DC425F0FE122 V1 EN (Equation 23)

High-resistance earthed network:

Yo Y YBgtot Rn= +

GUID-F91DA4E4-F439-4BFA-AA0D-5839B1574946 V1 EN (Equation 24)



≈+ ⋅ −( )I j I I

U

Rn eTot eFd

ph

GUID-CAA0C492-20CF-406C-80AC-8301375AB454 V1 EN (Equation 25)

YBgtot Sum of the phase-to-earth admittances (YBgA, YBgB, YBgC) of the background network

YCC Admittance of the earthing arrangement (compensation coil and parallel resistor)

IRcc Rated current of the parallel resistor

IeFd Magnitude of the earth-fault current of the protected feeder when the fault resistance is zero ohm

IeTot Magnitude of the uncompensated earth-fault current of the network when Rf is zero ohm

K Compensation degree, K = 1 full resonance, K<1 undercompensated, K>1 overcompensated

IRn Rated current of the neutral earthing resistor

Equation 20 shows that in case of a fault inside the protected feeder in unearthednetworks, the measured admittance equals the admittance of the backgroundnetwork. The admittance is dominantly reactive; the small resistive part of themeasured admittance is due to the leakage losses of the background network.Theoretically, the measured admittance is located in the first quadrant in theadmittance plane, close to the im(Yo) axis, see Figure 127.

Equation 22 shows that in case of a fault inside the protected feeder incompensated networks, the measured admittance equals the admittance of thebackground network and the coil including the parallel resistor. Basically, thecompensation degree determines the imaginary part of the measured admittanceand the resistive part is due to the parallel resistor of the coil and the leakage lossesof the background network and the losses of the coil. Theoretically, the measuredadmittance is located in the first or fourth quadrant in the admittance plane,depending on the compensation degree, see Figure 127.

Before the parallel resistor is connected, the resistive part of themeasured admittance is due to the leakage losses of the backgroundnetwork and the losses of the coil. As they are typically small, theresistive part may not be sufficiently large to secure thediscrimination of the fault and its direction based on the measuredconductance. This and the rating and the operation logic of theparallel resistor should be considered when setting the admittancecharacteristic in compensated networks.

Equation 24 shows that in case of a fault inside the protected feeder in high-resistance earthed systems, the measured admittance equals the admittance of thebackground network and the neutral earthing resistor. Basically, the imaginary partof the measured admittance is due to the phase-to-earth capacitances of thebackground network, and the resistive part is due to the neutral earthing resistorand the leakage losses of the background network. Theoretically, the measuredadmittance is located in the first quadrant in the admittance plane, see Figure 127.



Im(Yo)

Re(Yo)

Forward fault, unearthed network:

Yo ≈ j*(IeTot-IeFd)/Uph

Forward fault, compensated network:

Yo ≈ (Ircc + j*(IeTot*(1-K) - IeFd))/Uph

Under-comp. (K<1)

Resonance (K=1)

Over-comp. (K>1)

Reverse fault:

Yo ≈ -j*IeFd/Uph

Forward fault, high resistance earthed network:

Yo ≈ (IRn+j*(IeTot-IeFd))/Uph

~

~

~

A B C

EA

EB

EC

Io

Forward Fault

LccRcc

IeFdIeTot

(IeTot - IeFd)

Uo Rn

Protected feeder

Background network

YFd

YBg

GUID-5DB19698-38F9-433E-954F-4EBDBA5B63BD V1 EN

Figure 127: Admittance calculation during a forward fault

When the network is fully compensated in compensated networks,theoretically during a forward fault the imaginary part of themeasured admittance equals the susceptance of the protected feederwith a negative sign. The discrimination between a forward andreverse fault must therefore be based on the real part of themeasured admittance, that is, conductance. Thus, the best



selectivity is achieved when the compensated network is operatedeither in the undercompensated or overcompensated mode.

For example, in a 15 kV compensated network, the magnitude of the earth faultcurrent of the protected feeder is 10 A (Rf = 0 ohm) and the magnitude of thenetwork is 100 A (Rf = 0 ohm). During an earth fault, a 15 A resistor is connectedin parallel to the coil after a 1.0 second delay. Compensation degree isovercompensated, K = 1.1.

During an earth fault in the forward direction, that is, inside the protected feeder,the theoretical value for the measured admittance after the connection of theparallel resistor can be calculated:

YoI j I K I

U

A j A A

Rcc eTot eFd

ph

≈+ ⋅ ⋅ −( ) −( )

=+ ⋅ ⋅ −( ) −( )

1

15 100 1 1 1 10

15

.

kkVj

31 73 2 31≈ − ⋅( ). . milliSiemens

GUID-8763BA04-22DC-4B93-B52D-1E8FD44A68B9 V1 EN (Equation 26)

Before the parallel resistor is connected, the resistive part of the measuredadmittance is due to the leakage losses of the background network and the losses ofthe coil. As they are typically small, the resistive part may not be sufficiently largeto secure the discrimination of the fault and its direction based on the measuredconductance. This and the rating and the operation logic of the parallel resistorshould be considered when setting the admittance characteristic.

When a high sensitivity of the protection is required, the residualcurrent should be measured with a cable/ring core CT, that is, theFerranti CT. Also the use of the sensitive Io input should beconsidered. The residual voltage measurement should be done withan open delta connection of the three single pole-insulated voltagetransformers.

Operation characteristicAfter the admittance calculation is released, the calculated neutral admittance iscompared to the admittance characteristic boundaries in the admittance plane. If thecalculated neutral admittance Yo moves outside the characteristic, the enablingsignal is sent to the timer.

EFPADM supports a wide range of different characteristics to achieve themaximum flexibility and sensitivity in different applications. The basiccharacteristic shape is selected with the Operation mode and Directional modesettings. Operation mode defines which operation criterion or criteria are enabledand Directional mode defines if the forward, reverse or non-directional boundarylines for that particular operation mode are activated.



Table 277: Operation criteria

Operation mode DescriptionYo Admittance criterion

Bo Susceptance criterion

Go Conductance criterion

Yo, Go Admittance criterion combined with theconductance criterion

Yo, Bo Admittance criterion combined with thesusceptance criterion

Go, Bo Conductance criterion combined with thesusceptance criterion

Yo, Go, Bo Admittance criterion combined with theconductance and susceptance criterion

The options for the Directional mode setting are "Non-directional", "Forward" and"Reverse".

Figure 128, Figure 129 and Figure 130 illustrate the admittance characteristicssupported by EFPADM and the settings relevant to that particular characteristic.The most typical characteristics are highlighted and explained in details in thechapter Neutral admittance characteristics . Operation is achieved when thecalculated neutral admittance Yo moves outside the characteristic (the operationarea is marked with gray).

The settings defining the admittance characteristics are given inprimary milliSiemens (mS). The conversion equation for theadmittance from secondary to primary is:

Y Yni

nupri

CT

VT

= ⋅sec

GUID-2F4EAEF7-0D92-477F-8D4C-00C7BEDE04CB V1 EN (Equation 27)

niCT CT ratio for the residual current Io

nuVT VT ratio for the residual voltage Uo

Example: Admittance setting in the secondary is 5.00 milliSiemens.The CT ratio is 100/1 A and the VT ratio is 11547/100 V. Theadmittance setting in the primary can be calculated.

Y milliSiemensA

VmilliSiemenspri = ⋅ =5 00

100 1

11547 1004 33. .

GUID-9CFD2291-9894-4D04-9499-DF38F1F64D59 V1 EN



Operation mode

Yo Bo Go

Im(Yo)

Settings:•Circle conductance•Circle susceptance•Circle radius

Im(Yo)

Settings:•Susceptance forward•Susceptance reverse•Susceptance tilt Ang

Re(Yo)

Settings:•Conductance forward•Conductance reverse•Conductance tilt Ang

Re(Yo)

Im(Yo)

Re(Yo)

Not applicable in high resistance earthed or compensated systems!

Not applicable in unearthed systems!

Operation mode

Yo,Go Yo,Bo Go,Bo Yo,Go,Bo

Settings:•Circle conductance•Circle susceptance•Circle radius•Conductance forward•Conductance reverse•Conductance tilt Ang

Im(Yo) Im(Yo)

Settings:•Circle conductance•Circle susceptance•Circle radius•Susceptance forward•Susceptance reverse•Susceptance tilt Ang

Re(Yo)

Im(Yo)

Settings:•Conductance forward•Conductance reverse•Conductance tilt Ang•Susceptance forward•Susceptance reverse•Susceptance tilt Ang

Re(Yo)

Im(Yo)

Settings:•Circle conductance•Circle susceptance•Circle radius•Conductance forward•Conductance reverse•Conductance tilt Ang•Susceptance forward•Susceptance reverse•Susceptance tilt Ang

Re(Yo) Re(Yo)

GUID-FD8DAB15-CA27-40B0-9A43-FCF0881DB21E V1 EN

Figure 128: Admittance characteristic with different operation modes whenDirectional mode = "Non-directional"



Operation mode

Yo Bo Go


Settings:•Susceptance forward•Susceptance tilt Ang

Settings:•Conductance forward•Conductance tilt Ang

Im(Yo)

Re(Yo) Re(Yo)

Im(Yo)Im(Yo)

Re(Yo)



Operation mode


Settings:•Circle conductance•Circle susceptance•Circle radius•Conductance forward•Conductance tilt Ang

Settings:•Circle conductance•Circle susceptance•Circle radius•Susceptance forward•Susceptance tilt Ang

Settings:•Conductance forward•Conductance tilt Ang•Susceptance forward•Susceptance tilt Ang

Settings:•Circle conductance•Circle susceptance•Circle radius•Conductance forward•Conductance tilt Ang•Susceptance forward•Susceptance tilt Ang

Im(Yo) Im(Yo)

Re(Yo)

Im(Yo)

Re(Yo)

Im(Yo)

Re(Yo) Re(Yo)

GUID-7EDB14B9-64B4-449C-9290-70A4CC2D588F V1 EN

Figure 129: Admittance characteristic with different operation modes whenDirectional mode = "Forward"



Operation mode


Settings:•Susceptance reverse•Susceptance tilt Ang

Settings:•Conductance reverse•Conductance tilt Ang

Im(Yo)

Re(Yo) Re(Yo)

Im(Yo)Im(Yo)

Re(Yo)



Operation mode


Settings:•Circle conductance•Circle susceptance•Circle radius•Conductance reverse•Conductance tilt Ang

Settings:•Circle conductance•Circle susceptance•Circle radius•Susceptance reverse•Susceptance tilt Ang

Settings:•Conductance reverse•Conductance tilt Ang•Susceptance reverse•Susceptance tilt Ang

Settings:•Circle conductance•Circle susceptance•Circle radius•Conductance reverse•Conductance tilt Ang•Susceptance reverse•Susceptance tilt Ang

Im(Yo) Im(Yo)

Re(Yo)

Im(Yo)

Re(Yo)

Im(Yo)

Re(Yo)

Re(Yo)

GUID-C847609F-E261-4265-A1D9-3C449F8672A1 V1 EN

Figure 130: Admittance characteristic with different operation modes whenDirectional mode = "Reverse"

TimerOnce activated, the timer activates the START output. The time characteristic isaccording to DT. When the operation timer has reached the value set with theOperate delay time setting, the OPERATE output is activated. If the fault



disappears before the module operates, the reset timer is activated. If the reset timerreaches the value set with the Reset delay time setting, the operation timer resetsand the START output is deactivated. The timer calculates the start duration valueSTART_DUR, which indicates the percentage ratio of the start situation and the setoperation time. The value is available in the monitored data view.


The Blocking mode setting has three blocking methods. In the "Freeze timers"mode, the operate timer is frozen to the prevailing value. In the "Block all" mode,the whole function is blocked and the timers are reset. In the "Block OPERATEoutput" mode, the function operates normally but the OPERATE output is notactivated.

4.2.4.5 Neutral admittance characteristics

The applied characteristic should always be set to cover the total admittance of theprotected feeder with a suitable margin. However, more detailed setting valueselection principles depend on the characteristic in question.

The settings defining the admittance characteristics are given inprimary milliSiemens.

The forward and reverse boundary settings should be set so that the forward settingis always larger than the reverse setting and that there is space between them.

Overadmittance characteristicThe overadmittance criterion is enabled with the setting Operation mode set to"Yo". The characteristic is a circle with the radius defined with the Circle radiussetting. For the sake of application flexibility, the midpoint of the circle can bemoved away from the origin with the Circle conductance and Circle susceptancesettings. Default values for Circle conductance and Circle susceptance are 0.0 mS,that is, the characteristic is an origin-centered circle.

Operation is achieved when the measured admittance moves outside the circle.

The overadmittance criterion is typically applied in unearthed networks, but it canalso be used in compensated networks, especially if the circle is set off from the origin.



Im(Yo)

Re(Yo)

Circle radius

OPERATEOPERATE

OPERATE OPERATE

Im(Yo)

Re(Yo)

Circle radius

OPERATEOPERATE

OPERATE OPERATE

Circle conductance

Circle susceptance

GUID-AD789221-4073-4587-8E82-CD9BBD672AE0 V1 EN

Figure 131: Overadmittance characteristic. Left figure: classical origin-centeredadmittance circle. Right figure: admittance circle is set off from theorigin.

Non-directional overconductance characteristicThe non-directional overconductance criterion is enabled with the Operation modesetting set to "Go" and Directional mode to "Non-directional". The characteristic isdefined with two overconductance boundary lines with the Conductance forwardand Conductance reverse settings. For the sake of application flexibility, theboundary lines can be tilted by the angle defined with the Conductance tilt Angsetting. By default, the tilt angle is zero degrees, that is, the boundary line is avertical line in the admittance plane. A positive tilt value rotates the boundary linecounterclockwise from the vertical axis.

In case of non-directional conductance criterion, the Conductance reverse settingmust be set to a smaller value than Conductance forward.

Operation is achieved when the measured admittance moves over either of theboundary lines.

The non-directional overconductance criterion is applicable in high-resistance earthed and compensated networks. It must not beapplied in unearthed networks.



Re(Yo)

Im(Yo)

Conductance forward

Conductance reverse

Conductance tilt Ang <0

Re(Yo)

Im(Yo)

Conductance tilt Ang >0

Re(Yo)

Im(Yo)

OPERATEOPERATE

OPERATE OPERATE

OPERATEOPERATE

OPERATE OPERATE

OPERATEOPERATE

OPERATE OPERATE

Conductance forward

Conductance reverse

Conductance forward

Conductance reverse

GUID-F5487D41-6B8E-4A7A-ABD3-EBF7254ADC4C V1 EN

Figure 132: Non-directional overconductance characteristic. Left figure:classical non-directional overconductance criterion. Middle figure:characteristic is tilted with negative tilt angle. Right figure:characteristic is tilted with positive tilt angle.

Forward directional overconductance characteristicThe forward directional overconductance criterion is enabled with the Operationmode setting set to "Go" and Directional mode set to "Forward". The characteristicis defined by one overconductance boundary line with the Conductance forwardsetting. For the sake of application flexibility, the boundary line can be tilted withthe angle defined with the Conductance tilt Ang setting. By default, the tilt angle iszero degrees, that is, the boundary line is a vertical line in the admittance plane. Apositive tilt value rotates the boundary line counterclockwise from the vertical axis.

Operation is achieved when the measured admittance moves over the boundary line.

The forward directional overconductance criterion is applicable inhigh-resistance earthed and compensated networks. It must not beapplied in unearthed networks.

Re(Yo)

Im(Yo)

Conductance forward

Conductance tilt Ang <0

Re(Yo)

Im(Yo)


Re(Yo)

Im(Yo)

OPERATE

OPERATE

OPERATE

OPERATE

OPERATE

OPERATE

Conductance forward Conductance forward

GUID-43F312AA-874A-4CE7-ABFE-D76BA70B7A5D V1 EN

Figure 133: Forward directional overconductance characteristic. Left figure:classical forward directional overconductance criterion. Middlefigure: characteristic is tilted with negative tilt angle. Right figure:characteristic is tilted with positive tilt angle.



Forward directional oversusceptance characteristicThe forward directional oversusceptance criterion is enabled with the Operationmode setting set to "Bo" and Directional mode to "Forward". The characteristic isdefined by one oversusceptance boundary line with the Susceptance forwardsetting. For the sake of application flexibility, the boundary line can be tilted by theangle defined with the Susceptance tilt Ang setting. By default, the tilt angle is zerodegrees, that is, the boundary line is a horizontal line in the admittance plane. Apositive tilt value rotates the boundary line counterclockwise from the horizontal axis

Operation is achieved when the measured admittance moves over the boundary line.

The forward directional oversusceptance criterion is applicable inunearthed networks. It must not be applied in compensated networks.

Re(Yo) Re(Yo)Re(Yo)

Im(Yo)

Susceptance forward

Re(Yo)

Im(Yo)

Re(Yo)

Im(Yo)

OPERATEOPERATEOPERATEOPERATE OPERATEOPERATE

Susceptance forward Susceptance forward

Susceptance tilt Ang >0

Susceptance tilt Ang <0

GUID-43B0F2F9-38CE-4F94-8381-0F20A0668AB1 V1 EN

Figure 134: Forward directional oversusceptance characteristic. Left figure:classical forward directional oversusceptance criterion. Middlefigure: characteristic is tilted with negative tilt angle. Right figure:characteristic is tilted with positive tilt angle.

Combined overadmittance and overconductance characteristicThe combined overadmittance and overconductance criterion is enabled with theOperation mode setting set to "Yo, Go" and Directional mode to "Non-directional".The characteristic is a combination of a circle with the radius defined with theCircle radius setting and two overconductance boundary lines with the settingsConductance forward and Conductance reverse. For the sake of applicationflexibility, the midpoint of the circle can be moved from the origin with the Circleconductance and Circle susceptance settings. Also the boundary lines can be tiltedby the angle defined with the Conductance tilt Ang setting. By default, the Circleconductance and Circle susceptance are 0.0 mS and Conductance tilt Ang equalszero degrees, that is, the characteristic is a combination of an origin-centered circlewith two vertical overconductance boundary lines. A positive tilt value for theConductance tilt Ang setting rotates boundary lines counterclockwise from thevertical axis.



In case of the non-directional conductance criterion, the Conductance reversesetting must be set to a smaller value than Conductance forward. If this rule is notfollowed, a conflict situation is declared in the monitored data CONFLICT.

Operation is achieved when the measured admittance moves outside thecharacteristic.

The combined overadmittance and overconductance criterion is applicable inunearthed, high-resistance earthed and compensated networks or in systems wherethe system earthing may temporarily change during normal operation fromcompensated network to unearthed system.

Compared to the overadmittance criterion, the combined characteristic improvessensitivity in high-resistance earthed and compensated networks. Compared to thenon-directional overconductance criterion, the combined characteristic enables theprotection to be applied also in unearthed systems.

Re(Yo)

Im(Yo) Im(Yo)

OPERATEOPERATE

Re(Yo)Circle radius

Circle radiusCircle conductance

Circle susceptance

Conductance forward

Conductance reverse

OPERATEOPERATE

Conductance forward

Conductance reverse

OPERATEOPERATE

OPERATEOPERATE

Conductance tilt Ang

GUID-7AE09721-1428-4392-9142-A6D39FD4C287 V1 EN

Figure 135: Combined overadmittance and overconductance characteristic.Left figure: classical origin-centered admittance circle combinedwith two overconductance boundary lines. Right figure: admittancecircle is set off from the origin.

Combined overconductance and oversusceptance characteristicThe combined overconductance and oversusceptance criterion is enabled with theOperation mode setting set to "Go, Bo".

By setting Directional mode to "Forward", the characteristic is a combination oftwo boundary lines with the settings Conductance forward and Susceptanceforward. See Figure 136.

By setting Directional mode to "Non-directional", the characteristic is acombination of four boundary lines with the settings Conductance forward,Conductance reverse, Susceptance forward and Susceptance reverse. See Figure137.



For the sake of application flexibility, the boundary lines can be tilted by the angledefined with the Conductance tilt Ang and Susceptance tilt Ang settings. Bydefault, the tilt angles are zero degrees, that is, the boundary lines are straight linesin the admittance plane. A positive Conductance tilt Ang value rotates theoverconductance boundary line counterclockwise from the vertical axis. A positiveSusceptance tilt Ang value rotates the oversusceptance boundary linecounterclockwise from the horizontal axis.

In case of the non-directional conductance and susceptance criteria, theConductance reverse setting must be set to a smaller value than Conductanceforward and the Susceptance reverse setting must be set to a smaller value thanSusceptance forward.

Operation is achieved when the measured admittance moves outside thecharacteristic.

The combined overconductance and oversusceptance criterion is applicable in high-resistance earthed, unearthed and compensated networks or in the systems wherethe system earthing may temporarily change during normal operation fromcompensated to unearthed system.

Re(Yo)

Im(Yo)

Susceptance forward

OPERATEOPERATE

Conductance forward


OPERATE

Re(Yo)

Im(Yo)

Susceptance forward

OPERATE

OPERATE

Conductance forward

OPERATE


GUID-1A21391B-A053-432B-8A44-7D2BF714C52D V1 EN

Figure 136: Combined forward directional overconductance and forwarddirectional oversusceptance characteristic. Left figure: theConductance tilt Ang and Susceptance tilt Ang settings equal zerodegrees. Right figure: the setting Conductance tilt Ang > 0 degreesand the setting Susceptance tilt Ang < 0 degrees.



Re(Yo)

Im(Yo)

Susceptance forward

OPERATEOPERATE

Conductance forward

OPERATE

Susceptance reverse

OPERATE



Conductance reverse

GUID-0A34B498-4FDB-44B3-A539-BAE8F10ABDF0 V1 EN

Figure 137: Combined non-directional overconductance and non-directionaloversusceptance characteristic

The non-directional overconductance and non-directionaloversusceptance characteristic provides a good sensitivity andselectivity when the characteristic is set to cover the totaladmittance of the protected feeder with a proper margin.

4.2.4.6 Application

Neutral admittance protection provides a selective earth-fault protection functionfor high-resistance earthed, unearthed and compensated networks. It can be appliedfor the protection of overhead lines as well as with underground cables. It can beused as an alternative solution to traditional residual current-based earth-faultprotection functions, for example the IoCos mode in DEFxPDEF. Main advantagesof EFPADM include versatile applicability, good sensitivity and easy settingprinciples.

As a start condition for the neutral admittance protection, the residual overvoltagecondition is used. When the residual voltage exceeds the set threshold Voltage startvalue, an earth fault is detected and the neutral admittance calculation is released.In order to guarantee a high security of protection, that is, avoid false starts, theVoltage start value setting must be set above the highest possible value of Uo



during normal operation with a proper margin. It should consider all possibleoperation conditions and configuration changes in the network. In unearthedsystems, the healthy-state Uo is typically less than 1%xUph (Uph = nominal phase-to-earth voltage). In compensated networks, the healthy-state Uo may reach valueseven up to 30%xUph if the network includes large parts of overheadlines without aphase transposition. Generally, the highest Uo is achieved when the compensationcoil is tuned to the full resonance and when the parallel resistor of the coil is notconnected.

The residual overvoltage-based start condition for the admittance protectionenables a multistage protection principle. For example, one instance of EFPADMcould be used for alarming to detect faults with a high fault resistance using arelatively low value for the Voltage start value setting. Another instance ofEFPADM could then be set to trip with a lower sensitivity by selecting a highervalue of the Voltage start value setting than in the alarming instance (stage).

To apply the neutral admittance protection, at least the following network data arerequired:

• System earthing method• Maximum value for Uo during the healthy state• Maximum earth-fault current of the protected feeder when the fault resistance

Rf is zero ohm• Maximum uncompensated earth-fault current of the system (Rf = 0 ohm)• Rated current of the parallel resistor of the coil (active current forcing scheme)

in the case of a compensated neutral network• Rated current of the neutral earthing resistor in the case of a high-resistance

earthed system• Knowledge of the magnitude of Uo as a function of the fault resistance to

verify the sensitivity of the protection in terms of fault resistance

Figure 138 shows the influence of fault resistance on the residual voltagemagnitude in unearthed and compensated networks. Such information should beavailable to verify the correct Voltage start value setting, which helps fulfill therequirements for the sensitivity of the protection in terms of fault resistance.



0 10 20 30 40 50 60 70 80 90 1000

102030405060708090

100

Total earth f ault current (A), Rf = 0 ohm

Resi

dua

l vo

ltag

e (%

)

Resonance, K = 1

0 10 20 30 40 50 60 70 80 90 1000

102030405060708090

100

Total earth f ault current (A), Rf = 0 ohm

Resi

dua

l vo

ltag

e (%

)

Over/Under-Compensated, K = 1.2/0.8

0 10 20 30 40 50 60 70 80 90 1000

102030405060708090

100

Total earth fault current (A), Rf = 0 ohm

Resi

dua

l vo

ltag

e (%

)

Unearthed

Rf = 500 ohmRf = 2500 ohmRf = 5000 ohmRf = 10000 ohm

GUID-2F3654EF-9700-4FB7-B73C-85F7ED5D8EEF V1 EN

Figure 138: Influence of fault resistance on the residual voltage magnitude in10 kV unearthed and compensated networks. The leakageresistance is assumed to be 30 times larger than the absolutevalue of the capacitive reactance of the network. Parallel resistor ofthe compensation coil is assumed to be disconnected.

0 10 20 30 40 50 60 70 80 901000

102030405060708090

100


Res

idua

l vol

tage

(%)

Resonance, K = 1

0 10 20 30 40 50 60 70 80 901000

102030405060708090

100


Res

idua

l vol

tage

(%)


0 10 20 30 40 50 60 70 80 901000

102030405060708090

100


Res

idua

l vol

tage

(%)

Unearthed


GUID-3880FB01-5C89-4E19-A529-805208382BB1 V1 EN


0 10 20 30 40 50 60 70 80 901000

102030405060708090

100


Res

idua

l vol

tage

(%)

Resonance, K = 1

0 10 20 30 40 50 60 70 80 901000

102030405060708090

100


Res

idua

l vol

tage

(%)


0 10 20 30 40 50 60 70 80 901000

102030405060708090

100


Res

idua

l vol

tage

(%)

Unearthed


GUID-6321328D-6C17-4155-A2DF-7E1C47A44D53 V1 EN




ExampleIn a 15 kV, 50 Hz compensated network, the maximum value for Uo during thehealthy state is 10%xUph. Maximum earth-fault current of the system is 100 A.The maximum earth fault current of the protected feeder is 10 A (Rf = 0 ohm). Theapplied active current forcing scheme uses a 15 A resistor, which is connected inparallel to the coil during the fault after a 1.0 second delay.

Solution: As a start condition for the neutral admittance protection, the internalresidual overvoltage condition of EFPADM is used. The Voltage start value settingmust be set above the maximum healthy-state Uo of 10%xUph with a suitable margin.

Voltage start value = 0.15 xUn

According to Figure 139, this selection ensures at least a sensitivity correspondingto a 2000 ohm fault resistance when the compensation degree varies between 80%and 120%. The greatest sensitivity is achieved when the compensation degree isclose to full resonance.

An earth-fault current of 10 A can be converted into admittance.

YA

kVjFdtot = ≈ ⋅

10


GUID-3631BAB9-7D65-4591-A3D6-834687D0E03C V1 EN

A parallel resistor current of 15 A can be converted into admittance.

GA

kVcc = ≈

15


GUID-4B7A18DE-68CB-42B2-BF02-115F0ECC03D9 V1 EN

According to Equation 17, during an outside fault EFPADM measures thefollowing admittance:

Yo Y jFdtot= − ≈ − ⋅1 15. milliSiemens

GUID-AD02E209-1740-4930-8E28-AB85637CEF0D V1 EN

According to Equation 22, during an inside fault EFPADM measures theadmittance after the connection of the parallel resistor:

Yo Y Y j BBgtot CC= + ≈ + ⋅( )1 73. milliSiemens

GUID-28AF4976-1872-48A1-ACC7-7CC3B51CD9D8 V1 EN

Where the imaginary part of the admittance, B, depends on the tuning of the coil(compensation degree).

The admittance characteristic is selected to be the combined overconductance andoversusceptance characteristic with four boundary lines:

Operation mode = "Go, Bo"

Directional mode = "Non-directional"



The admittance characteristic is set to cover the total admittance of the protectedfeeder with a proper margin, see Figure 141.

Conductance forward = 1.73 mS · 0.2 ≈ 0.35 mS

Conductance reverse = -1.0 mS (valid range apprx. 0.5 · 1.15 - 1.2 · 1.73 = -0.6...-2.1)

Susceptance forward = 0.1 mS

Susceptance reverse = -1.15 mS · 1.2 ≈ -1.4 mS

-5 -4 -3 -2 -1 0 1 2 3 4 5-5

-4

-3

-2

-1

0

1

2

3

4

5Go (mS)

Bo (mS)

Backward fault:

Yo ≈ -j*1.15mS Forward fault,

Yo ≈ 1.73+j*Bo mS

-5 -4 -3 -2 -1 0 1 2 3 4 5-5

-4

-3

-2

-1

0

1

2

3

4

5Go (mS)

Bo (mS)

0.35 mS-1.0 mS

-1.4 mS

0.1 mS

OPERATE OPERATE

OPERATE OPERATE

GUID-AE9BB46E-B927-43F6-881A-A96D3410268D V1 EN

Figure 141: Admittances of the example

4.2.4.7 Signals

Table 278: EFPADM Input signals




RELEASE BOOLEAN 0=False External trigger to release neutral admittanceprotection

Table 279: EFPADM Output signals


START BOOLEAN Start



4.2.4.8 Settings

Table 280: EFPADM Group settings

Parameter Values (Range) Unit Step Default DescriptionVoltage start value 0.01...2.00 xUn 0.01 0.15 Voltage start value



Operation mode 1=Yo2=Go3=Bo4=Yo, Go5=Yo, Bo6=Go, Bo7=Yo, Go, Bo

1=Yo Operation criteria


Circle radius 0.05...500.00 mS 0.01 1.00 Admittance circle radius

Circle conductance -500.00...500.00 mS 0.01 0.00 Admittance circle midpoint, conductance

Circle susceptance -500.00...500.00 mS 0.01 0.00 Admittance circle midpoint, susceptance

Conductance forward -500.00...500.00 mS 0.01 1.00 Conductance threshold in forwarddirection

Conductance reverse -500.00...500.00 mS 0.01 -1.00 Conductance threshold in reversedirection

Conductance tilt Ang -30...30 deg 1 0 Tilt angle of conductance boundary line

Susceptance forward -500.00...500.00 mS 0.01 1.00 Susceptance threshold in forwarddirection

Susceptance reverse -500.00...500.00 mS 0.01 -1.00 Susceptance threshold in reversedirection

Susceptance tilt Ang -30...30 deg 1 0 Tilt angle of susceptance boundary line

Table 281: EFPADM Non group settings



Admittance Clc mode 1=Normal2=Delta

1=Normal Admittance calculation mode








Uo signal Sel 1=Measured Uo2=Calculated Uo

1=Measured Uo Selection for used Uo signal




Table 282: EFPADM Monitored data


operate time



COND_RES FLOAT32 -1000.00...1000.00

mS Real part of calculatedneutral admittance

SUS_RES FLOAT32 -1000.00...1000.00

mS Imaginary part ofcalculated neutraladmittance

EFPADM Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 283: EFPADM Technical data

Characteristic ValueOperation accuracy1) At the frequency f = fn

±1.0% or ±0.01 mS(In range of 0.5 - 100 mS)

Start time2) Minimum Typical Maximum

56 ms 60 ms 64 ms

Reset time 40 ms

Operate time accuracy ±1.0% of the set value of ±20 ms

Suppression ofharmonics

-50 dB at f = n x fn, where n = 2, 3, 4, 5,…

1) Uo = 1.0 x Un2) Includes the delay of the signal output contact. Results based on statistical distribution of 1000

measurements.

4.2.5 Harmonic based earth-fault protection HAEFPTOC


Description IEC 61850identification


ANSI/IEEEidentification

Harmonics earth-fault protection HAEFPTOC Io>HA 51NHA




OPERATE

START

Io

HAEFPTOC

I_REF_RES

BLOCK

GUID-A27B40F5-1E7D-4880-BBC4-3B07B73E9067 V2 EN


4.2.5.3 HAEFPTOC functionality

The harmonics earth-fault protection HAEFPTOC is used instead of a traditionalearth-fault protection in networks where a fundamental frequency component ofthe earth-fault current is low due to compensation.

By default, HAEFPTOC is used as a standalone mode. Substation-wide applicationcan be achieved using horizontal communication where the detection of a faultyfeeder is done by comparing the harmonics earth-fault current measurements.

The function starts when the harmonics content of the earth-fault current exceedsthe set limit. The operation time characteristic is either definite time (DT) orinverse definite minimum time (IDMT). If the horizontal communication is usedfor the exchange of current values between the IEDs, the function operatesaccording to the DT characteristic.

The function contains a blocking functionality. It is possible to block functionoutputs, timer or the function itself, if desired.



The operation of the harmonics earth-fault protection can be described using amodule diagram. All the modules in the diagram are explained in the next sections.



GUID-DFEDB90A-4ECE-4BAA-9987-87F02BA0798A V2 EN


Harmonics calculationThis module feeds the measured residual current to the high-pass filter, where thefrequency range is limited to start from two times the fundamental frequency of thenetwork (for example, in a 50 Hz network the cutoff frequency is 100 Hz), that is,summing the harmonic components of the network from the second harmonic. Theoutput of the filter, later referred to as the harmonics current, is fed to the Leveldetector and Current comparison modules.

The harmonics current I_HARM_RES is available in the monitored data view. Thevalue is also sent over horizontal communication to the other IEDs on the parallelfeeders configured in the protection scheme.



Nor

mal

ized

out

put

0.5

00

1.0

Frequency2ff

GUID-F05BA8C4-AC2B-420C-AE9D-946E815682D5 V1 EN

Figure 144: High-pass filter

Level detectorThe harmonics current is compared to the Start value setting. If the value exceedsthe value of the Start value setting, Level detector sends an enabling signal to theTimer module.

Current comparisonThe maximum of the harmonics currents reported by other parallel feeders in thesubstation, that is, in the same busbar, is fed to the function through theI_REF_RES input. If the locally measured harmonics current is higher thanI_REF_RES, the enabling signal is sent to Timer.

If the locally measured harmonics current is lower than I_REF_RES, the fault isnot in that feeder. The detected situation blocks Timer internally, andsimultaneously also the BLKD_I_REF output is activated.

The module also supervises the communication channel validity which is reportedto the Timer.

TimerThe START output is activated when Level detector sends the enabling signal.Functionality and the time characteristics depend on the selected value of theEnable reference use setting.



Table 284: Values of the Enable reference use setting

Enable reference use FunctionalityStandalone In the standalone mode, depending on the value of the

Operating curve type setting, the time characteristics areaccording to DT or IDMT. When the operation timer hasreached the value of the Operate delay time setting inthe DT mode or the value defined by the inverse timecurve, the OPERATE output is activated.

Reference use Communicationvalid

When using the horizontal communication, the functionis forced to use the DT characteristics. When theoperation timer has reached the value of the Minimumoperate time setting and simultaneously the enablingsignal from the Current comparison module is active, theOPERATE signal is activated.

Communicationinvalid

Function operates as in the standalone mode.

The Enable reference use setting forces the function to use the DTcharacteristics where the operating time is set with the Minimumoperate time setting.

If the communication for some reason fails, the function switches to use theOperation curve type setting, and if DT is selected, Operate delay time is used. Ifthe IDMT curve is selected, the time characteristics are according to the selectedcurve and the Minimum operate time setting is used for restricting too fast anoperation time.

In case of a communication failure, the start duration may change substantiallydepending on the user settings.

When the programmable IDMT curve is selected, the operation time characteristicsare defined with the Curve parameter A, Curve parameter B, Curve parameter C,Curve parameter D and Curve parameter E parameters.

If a drop-off situation happens, that is, a fault suddenly disappears before theoperation delay is exceeded, the Timer reset state is activated. The functionality ofTimer in the reset state depends on the combination of the Operating curve type,Type of reset curve and Reset delay time settings. When the DT characteristic isselected, the reset timer runs until the value of the Reset delay time setting isexceeded. When the IDMT curves are selected, the Type of reset curve setting canbe set to "Immediate", "Def time reset" or "Inverse reset". The reset curve type"Immediate" causes an immediate reset. With the reset curve type "Def time reset",the reset time depends on the Reset delay time setting. With the reset curve type"Inverse reset", the reset time depends on the current during the drop-off situation.If the drop-off situation continues, the reset timer is reset and the START output isdeactivated.

The "Inverse reset" selection is only supported with ANSI or theprogrammable types of the IDMT operating curves. If another



operating curve type is selected, an immediate reset occurs duringthe drop-off situation.

The setting Time multiplier is used for scaling the IDMT operation and reset times.

The setting parameter Minimum operate time defines the minimum desiredoperation time for IDMT. The setting is applicable only when the IDMT curves areused

The Minimum operate time setting should be used with great carebecause the operation time is according to the IDMT curve butalways at least the value of the Minimum operate time setting. Moreinformation can be found in the IDMT curves for overcurrentprotection .

Timer calculates the start duration value START_DUR, which indicates thepercentage ratio of the start situation, and the set operating time, which can beeither according to DT or IDMT. The value is available in the monitored data view.

More information can be found in the General function block features .



4.2.5.5 Application

During an earth fault, HAEFPTOC calculates the maximum current for the currentfeeder. The value is sent over an analog GOOSE to other IEDs of the busbar in thesubstation. At the configuration level, all the values received over the analogGOOSE are compared through the MAX function to find the maximum value. Themaximum value is sent back to HAEFPTOC as the I_REF_RES input. Theoperation of HAEFPTOC is allowed in case I_REF_RES is lower than the locallymeasured harmonics current. If I_REF_RES exceeds the locally measuredharmonics current, the operation of HAEFPTOC is blocked.



AnalogueGOOSE receive



MAX AnalogueGOOSE

send

HAEFPTOC

I_REF_RESBLOCK

STARTOPERATE

Io

I_HARM_RESBLKD_I_REF

GUID-4F4792F0-B311-4EB2-8EC8-56F062592158 V1 EN

Figure 145: Protection scheme based on the analog GOOSE communicationwith three analog GOOSE receivers

4.2.5.6 Signals

Table 285: HAEFPTOC Input signals



I_REF_RES FLOAT32 0.0 Reference current

Table 286: HAEFPTOC Output signals


START BOOLEAN Start



4.2.5.7 Settings

Table 287: HAEFPTOC Group settings









Enable reference use 0=False1=True

0=False Enable using current reference fromother IEDs instead of stand-alone

Table 288: HAEFPTOC Non group settings












Table 289: HAEFPTOC Monitored data


operate time

I_HARM_RES FLOAT32 0.0...30000.0 A Calculated harmonicscurrent

BLKD_I_REF BOOLEAN 0=False1=True

Current comparisonstatus indicator

HAEFPTOC Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 290: HAEFPTOC Technical data


measured: fn ±2 Hz

±5 % of the set value or ±0.004 x In

Start time 1)2) Typical 77 ms

Reset time < 40 ms



Operate time accuracy in IDMT mode 3) ±5.0% of the set value or ±20 ms

Suppression of harmonics -50dB at f= fn

-3dB at f= 13 x fn

1) Fundamental frequency current = 1.0 x In. Harmonics current before fault = 0.0 x In, harmonics faultcurrent 2.0 x Start value. Results based on statistical distribution of 1000 measurement.

2) Includes the delay of the signal output contact3) Maximum Start value = 2.5 x In, Start value multiples in range of 2 to 20

4.2.6 Wattmetric earth-fault protection WPWDE





Wattmetric earth-fault protection WPWDE Po>-> 32N




GUID-EDE21448-13FD-44E3-AF7C-CFD47A5C99DC V1 EN



The wattmetric earth-fault protection function WPWDE can be used to detect earthfaults in networks with a high-impedance earthing, unearthed networks orcompensated networks (Petersen coil-earthed networks). It can be used as analternative solution to the traditional residual current-based earth-fault protectionfunctions, for example, the IoCos mode in the directional earth-fault protectionfunction DEFxPDEF.

The function measures the earth-fault power IoUoCosφ and gives an operatingsignal when the residual current, residual voltage and earth-fault power exceed theset limits and the angle between the residual current and residual voltage (φ) isinside the set operating sector, that is, forward or backward sector. The operatingtime characteristic can be selected to be either definite time (DT) or a specialwattmetric-type inverse definite minimum type (wattmetric type IDMT).

The wattmetric earth-fault protection is very sensitive to current transformer errorsand it is recommended that a core balance CT is used for measuring the residualcurrent.




The operation of the wattmetric earth-fault protection function can be describedwith a module diagram. All the modules in the diagram are explained in the nextsections.



Directionalcalculation

Leveldetector

Io

Residualpower

calculation

Uo

BLOCK

OPERATE

START

RCA_CTL

t

Timer

t

Blockinglogic

GUID-2E3B73F0-DB0D-4E84-839F-8E12D6528EEC V1 EN

Figure 147: Function module diagram

Directional calculationThe Directional calculation module monitors the angle between the operatingquantity (residual current) and polarizing quantity (residual voltage). The operatingquantity can be selected with the setting Io signal Sel. The selectable options are“Measured Io” and “Calculated Io”. The polarizing quantity can be selected withthe setting Pol signal Sel. The selectable options are “Measured Uo” and“Calculated Uo”. When the angle between operating quantity and polarizingquantity after considering the Characteristic angle setting is in the operation sector,the module sends an enabling signal to Level detector. The directional operation isselected with the Directional mode setting. Either the “Forward” or “Reverse”operation mode can be selected. The direction of fault is calculated based on thephase angle difference between the operating quantity and polarizing quantity, thevalue (ANGLE) is available in the monitored data view.

The polarizing quantity for a directional earth fault is shifted by180° and hence it is represented as –Uo in the phasor diagrams.

If the angle difference lies between -90° to 0° or 0° to +90°, a forward directionfault is considered. If the phase angle difference lies within -90° to -180° or +90° to+180°, a reverse direction fault is detected. Thus the normal width of a sector is 180°.



GUID-A665FD59-1AD1-40B0-9741-A5DBFD0D0F2E V1 EN

Figure 148: Definition of the relay characteristic angle

The phase angle difference is calculated based on the Characteristic angle setting(also known as Relay Characteristic Angle (RCA) or Relay Base Angle orMaximum Torque Angle (MTA)). The Characteristic angle setting is done basedon the method of earthing employed in the network. For example, in case of anunearthed network the Characteristic angle setting is set to -90° and in case of acompensated network, the Characteristic angle setting is set to 0°. In general,Characteristic angle is selected so that it is close to the expected fault angle value,which results in maximum sensitivity. Characteristic angle can be set anywherebetween -179° to +180°. Thus, the effective phase angle (ϕ) for calculating theresidual power considering characteristic angle is

φ = ∠ − − ∠ −( )( )Uo Io Characteristic angle

In addition, the characteristic angle can be changed via the control signalRCA_CTL. The RCA_CTL input is used in the compensated networks where thecompensation coil sometimes is temporarily disconnected. When the coil isdisconnected, the compensated network becomes isolated and the Characteristicangle setting must be changed. This can be done automatically with the RCA_CTLinput, which results in the addition of -90° in the Characteristic angle setting.

The value (ANGLE_RCA) is available in the monitored data view.



-Uo (Polarizing quantity)

Forward area

Io (Operating quantity)

RCA = -90˚

Maximum torque line

Backward area

Minimumoperate current

Forward area Backward area

GUID-AA58DBE0-CBFC-4820-BA4A-195A11FE273B V1 EN

Figure 149: Definition of relay characteristic angle, RCA = -90° in an isolatednetwork

Characteristic angle should be set to a positive value if theoperating signal lags the polarizing signal and to a negative value ifthe operating signal leads the polarizing signal.

Type of network Characteristic angle recommendedCompensated network 0°

Unearthed network -90°

In unearthed networks, when the characteristic angle is -90°, themeasured residual power is reactive (varmetric power).

The fault direction is also indicated FAULT_DIR (available in the monitored dataview), which indicates 0 if a fault is not detected, 1 for faults in the forwarddirection and 2 for faults in the backward direction.

The direction of the fault is detected only when the correct angle calculation can bemade. If the magnitude of the operating quantity or polarizing quantity is not highenough, the direction calculation is not reliable. Hence, the magnitude of theoperating quantity is compared to the Min operate current setting and themagnitude of the polarizing quantity is compared to Min operate voltage, and ifboth the operating quantity and polarizing quantity are higher than their respectivelimit, a valid angle is calculated and the residual power calculation module is enabled.

The Correction angle setting can be used to improve the selectivity when there areinaccuracies due to the measurement transformer. The setting decreases the



operation sector. The Correction angle setting should be done carefully as thephase angle error of the measurement transformer varies with the connected burdenas well as with the magnitude of the actual primary current that is being measured.An example of how Correction angle alters the operating region is as shown:


Backwardarea

Forwardarea


Zero torque line


Maximum torque line forward direction (RCA = 0˚)

Correction angleCorrection angle

Forwardarea

Backwardarea

GUID-B420E2F4-8293-4330-A7F3-9A002940F2A4 V1 EN

Figure 150: Definition of correction angle

The polarity of the polarizing quantity can be changed (rotated by180°) by setting Pol reversal to "True" or by switching the polarityof the residual voltage measurement wires.

Residual power calculationThe Residual power calculation module calculates the magnitude of residual powerIoUoCosϕ. Angle ϕ is the angle between the operating quantity and polarizingquantity, compensated with a characteristic angle. The angle value is received fromthe Directional calculation module. The Directional calculation module enables theresidual power calculation only if the minimum signal levels for both operatingquantity and polarizing quantity are exceeded. However, if the angle calculation isnot valid, the calculated residual power is zero. Residual power (RES_POWER) iscalculated continuously and it is available in the monitored data view.

Level detectorLevel detector compares the magnitudes of the measured operating quantity,polarizing quantity and calculated residual power to the set Current start value,Voltage start value and Power start value respectively. When all three quantitiesexceed the limits, Level detector enables the Timer module.



TimerOnce activated, Timer activates the START output. Depending on the value of theOperating curve type setting, the time characteristics are according to DT orwattmetric IDMT. When the operation timer has reached the value of Operatedelay time in the DT mode or the maximum value defined by the inverse timecurve, the OPERATE output is activated. If a drop-off situation happens, that is, afault suddenly disappears before the operating delay is exceeded, the timer resetstate is activated. The reset time is identical for both DT or wattmeter IDMT. Thereset time depends on the Reset delay time setting.

Timer calculates the start duration value START_DUR, which indicates thepercentage ratio of the start situation and the set operation time. The value isavailable in the monitored data view.




In the wattmetric IDMT mode, the OPERATE output is activated based on thetimer characteristics:

t sk P

Pcal

[ ]*

=

ref

GUID-FEA556F2-175E-4BDD-BD0F-52E9F5499CA8 V2 EN (Equation 28)

t[s] operation time in seconds

k set value of Time multiplier

Pref set value of Reference power

Pcal calculated residual power



GUID-D2ABEA2C-B0E3-4C60-8E70-404E7C62C5FC V1 EN



Figure 151: Operation time curves for wattmetric IDMT for Sref set at 0.15 xPn



4.2.6.7 Application

The wattmetric method is one of the commonly used directional methods fordetecting the earth faults especially in compensated networks. The protection usesthe residual power component IoUoCosφ (φ is the angle between the polarizingquantity and operating quantity compensated with a relay characteristic angle).


Uo

Backward area

Forwardarea


Zero torque line(RCA = 0˚)


GUID-4E73135C-CEEF-41DE-8091-9849C167C701 V1 EN

Figure 152: Characteristics of wattmetric protection

In a fully compensated radial network with two outgoing feeders, the earth-faultcurrents depend mostly on the system earth capacitances (C0) of the lines and thecompensation coil (L). If the coil is tuned exactly to the system capacitance, thefault current has only a resistive component. This is due to the resistances of thecoil and distribution lines together with the system leakage resistances (R0). Oftena resistor (RL) in parallel with the coil is used for increasing the fault current.

When a single phase-to-earth fault occurs, the capacitance of the faulty phase isbypassed and the system becomes unsymmetrical. The fault current is composed ofthe currents flowing through the earth capacitances of two healthy phases. Theprotection relay in the healthy feeder tracks only the capacitive current flowingthrough its earth capacitances. The capacitive current of the complete network



(sum of all feeders) is compensated with the coil. An undercompensated networkwhere the coil current IL = ICtot - ICfd (ICtot is the total earth-fault current of thenetwork and ICfd is the earth-fault current of the healthy feeder) is as shown:

A B C

U0

C0

ΣI01

ΣI02

- U0

ΣI02

R0

L RL

- U0

ΣI01

IL

ICfd

Ictot = Ief

GUID-A524D89C-35D8-4C07-ABD6-3A6E21AF890E V1 EN

Figure 153: Typical radial compensated network employed with wattmetricprotection

The wattmetric function is activated when the residual active power componentexceeds the set limit. However, to ensure a selective operation it is also requiredthat the residual current and residual voltage also exceed the set limit.

The sensitivity of the wattmetric method is determined by the magnitude of theresidual voltage, which in turn is determined by the fault resistance and maximumhealthy-state residual voltage. The threshold value of the residual voltage must beset above the maximum healthy-state residual voltage value with a proper margin.When the fault resistance values are high, there is a reduction in the residualvoltage, which reduces the active residual power.

It is highly recommended that core balance CTs are used for measuring Io whenusing the wattmetric method. When a low transformation ratio is used, the CT cansuffer accuracy problems and even a distorted secondary current waveform withsome core balance CTs. Therefore, to ensure a sufficient accuracy of the residualcurrent measurement and consequently a better selectivity of the scheme, the corebalance current transformer should preferably have a transformation ratio of atleast 70:1. Lower transformation ratios such as 50:1 or 50:5 are not recommended,unless the phase displacement errors and CT amplitude are checked first.

It is not recommended to use the directional wattmetric protection in case of a ringor meshed system as the wattmetric requires a radial power flow to operate.



The relay characteristic angle needs to be set based on the system earthing. In anunearthed network, that is, the network is only coupled to earth via thecapacitances between the phase conductors and earth, the characteristic angle ischosen as -90º.

In compensated networks, the capacitive fault current and inductive resonance coilcurrent compensate each other, meaning that the fault current is mainly resistiveand has zero phase shift compared to the residual voltage. In such networks, thecharacteristic angle is chosen as 0º. Often the magnitude of active component issmall and must be increased by means of a parallel resistor in a compensation coil.In networks where the neutral point is earthed through a low resistance, thecharacteristic angle is always 0º.

As the amplitude of the residual current is independent of the fault location, theselectivity of the earth-fault protection is achieved with time coordination.

Use of wattmetric protection gives a possibility to use the dedicated inversedefinite minimum time characteristics. This is applicable in large high-impedanceearthed networks with a large capacitive earth-fault current.

In a network employing a low-impedance earthed system, a medium-size neutralpoint resistor is used. Such a resistor gives a resistive earth-fault current componentof about 200 - 400 A for an excessive earth fault. In such a system, the directionalresidual power protection gives better possibilities for selectivity enabled by theinverse time power characteristics.

Along with the wattmetric protection, it is recommended that the normal non-directional residual current function and non-directional residual voltage functionare also used (can be with definite or inverse time delay). The non-directionalresidual current function compares the residual current without checking any phaseangles and gives a quick protection under cross-country faults. The start valuesetting for this non-directional current function should be higher than the setting forall single-phase earth faults with a short IDMT time delay. This is an alternative tothe distance protection with the phase preference logic. The zero-sequence currentfor cross-country faults flowing through the feeder is high compared to the zero-sequence current of the single-phase earth fault. Under this condition, the corebalance CT tends to be saturated as it is not designed for a large zero-sequencecurrent which results in an inaccurate measurement. Hence, the phase currents areused to calculate the residual current. Non-directional residual voltage functionwith a long timer setting acts as a backup protection.

Due to the residual connection of the three-phase CTs and the open deltaconnection of the three-phase VTs, the third harmonic currents and voltages ofeach phase add up and pollute the residual current and voltage measurements. TheDFT measuring mode is used to enable a sensitive setting.



4.2.6.8 Signals

Table 291: WPWDE Input signals





Table 292: WPWDE Output signals


START BOOLEAN Start

4.2.6.9 Settings

Table 293: WPWDE Group settings

Parameter Values (Range) Unit Step Default DescriptionDirectional mode 2=Forward

3=Reverse 2=Forward Directional mode

Current start value 0.010...5.000 xIn 0.001 0.010 Minimum operate residual current fordeciding fault direction

Voltage start value 0.010...1.000 xUn 0.001 0.010 Start value for residual voltage

Power start value 0.003...1.000 xPn 0.001 0.003 Start value for residual active power

Reference power 0.050...1.000 xPn 0.001 0.150 Reference value of residual power forWattmetric IDMT curves


Time multiplier 0.05...2.00 0.01 1.00 Time multiplier for Wattmetric IDMTcurves

Operating curve type 5=ANSI Def. Time15=IEC Def. Time20=WattmetricIDMT


Operate delay time 60...200000 ms 10 60 Operate delay time for definite time

Table 294: WPWDE Non group settings




2=DFT Selects used current measurement mode





Parameter Values (Range) Unit Step Default DescriptionMin operate current 0.010...1.000 xIn 0.001 0.010 Minimum operating current







Pol signal Sel 1=Measured Uo2=Calculated Uo



Table 295: WPWDE Monitored data




START_DUR FLOAT32 0.00...100.00 Ratio of start time /operate time





RES_POWER FLOAT32 0.000...1048575.000

xPn Calculated residualactive power

WPWDE Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 296: WPWDE Technical data


measured: fn ±2 Hz

Current and voltage: ±1.5 % of the set value or±0.002 x In Power: ±3 % of the set value or±0.002 x Pn

Start time 1)2) Typical 63 ms




Characteristic ValueReset time < 40 ms



Operate time accuracy in IDMT mode ±5.0% of the set value or ±20 ms

Suppression of harmonics -50dB at F= n x fn, where n=2,3,4,5,…

1) Io varied during the test. Uo = 1.0 x Un = phase to earth voltage during earth-fault in compensatedor un-earthed network. The residual power value before fault = 0.0 p.u., fn = 50 Hz, results basedon statistical distribution of 1000 measurement.

2) Includes the delay of the signal output contact.

4.3 Differential protection

4.3.1 Line differential protection and related measurements,stabilized and instantaneous stages LNPLDF





Line differential protection and relatedmeasurements, stabilized andinstantaneous stages

LNPLDF 3dI>L 87L


GUID-F7ECAC0B-14B5-444C-9282-59AC32380576 V1 EN



The phase segregated line differential protection LNPLDF is used as feederdifferential protection for the distribution network lines and cables. LNPLDFincludes low, stabilized and high, non-stabilized stages.



The stabilized low stage provides a fast clearance of faults while remaining stablewith high currents passing through the protected zone increasing errors on currentmeasuring. Second harmonic restraint insures that the low stage does not operatedue to the startup of the tapped transformer. The high stage provides a very fastclearance of severe faults with a high differential current regardless of theirharmonics.

The operating time characteristic for the low stage can be selected to be eitherdefinite time (DT) or inverse definite time (IDMT). The direct inter-trip ensuresboth ends are always operated, even without local criteria.



The function can also be set into test mode by setting the Operation setting to “Test/blocked”.

The operation of the line differential protection and related measurements,stabilized and instantaneous stages can be described using a module diagram. Allthe modules in the diagram are explained in the next sections.

GUID-44304073-30AC-4EEA-889C-2D9410DC1180 V1 EN

Figure 155: Functional module diagram. I_LOC_x stands for current of the localend and I_REM_x for phase currents of the remote ends.

Inrush detectorThe transformer inrush currents cause high degrees of second harmonic to themeasured phase currents. The inrush detector detects inrush situations intransformers. The second harmonic based local blocking is selected into use with



the Restraint mode parameter. The blocking for the low stage on the local end isissued when the second harmonic blocking is selected and the inrush is detected.

The inrush detector calculates the ratio of the second harmonic currentI_2H_LOC_A and the fundamental frequency current I_1H_LOC_A. Thecalculated value is compared with the parameter value of the Start value 2.Hsetting. If the calculated value exceeds the set value and the fundamental frequencycurrent I_1H_LOC_A is more that seven percent of the nominal current, the outputsignal BLK2H_A is activated. The inrush detector handles the other phases thesame way.

The locally detected transformer inrush is also transferred to the remote end as abinary indication signal independently of the local Restraint mode settingparameter value. When the internal blocking of the stabilized low stage isactivated, the RSTD2H_LOC and RSTD2H_REM outputs will also be activated atthe same time depending on whether the inrush has been detected on local orremote end or on both ends.

GUID-92818F6B-4FB7-4D5C-AF64-36786F31AED8 V1 EN

Figure 156: Inrush current detection logic

Differential calculationThe operating principle is to calculate on both ends differential current fromcurrents entering and leaving the protection zone by utilizing the digitalcommunication channels for data exchange. The differential currents are almostzero on normal operation. The differential protection is phase segregated and thedifferential currents are calculated on both ends separately.



GUID-FD294556-1B8C-4054-ABF0-31DD6380BB56 V1 EN

Figure 157: Basic protection principle

The differential current I∆ (Id) of the IED is obtained on both ends with the formula:

I I Id LOC REM= +

GUID-9C08695B-8241-4B74-AA2A-B64783F9C288 V2 EN (Equation 29)

The stabilizing current Ibias (Ib) of the IED is obtained on both ends with the formula:

I

I I

b

LOC REM

=

−

2

GUID-6014FAFC-12CB-4DB3-85A9-0EF254D1729D V2 EN (Equation 30)

Depending on the location of the star points of the current transformers, thepolarity of the local end remote currents may be different causing malfunction ofthe calculation algorithms. The CT transformation ratio may be different and thisneeds to be compensated to provide a correct differential current calculation resulton both ends.

The operation characteristics related settings are given in units as percentage of thecurrent transformer secondary nominal current on each line end IED. For the actualprimary setting, the corresponding CT ratio on each line end has to be considered.An example of how the CT ratio correction parameter values should be selected onboth line ends in the example case to compensate the difference in the nominallevels can be presented. For example, 160A in the primary circuit would equal 160A/800Ax100% = 20% as the setting value for IED (A) and 160A/400Ax100% = 40%for IED (B). The CT ratio correction setting parameter is provided in case currenttransformers with different ratios are used in the two IEDs. This has no effect onthe actual protection stage settings.



GUID-646CC890-AEE6-4217-87FC-9D0BA06B207C V1 EN

Figure 158: Example of differential current during external fault

CT connection type is chosen based on two possibilities:

• "Type 1" is selected on both ends when the secondary current direction forlocal and remote secondary is the opposite (default). "Type 1" should be usedwhen the star point of the current transformer is located on the bus bar side onboth line end IEDs or alternatively, when the star point of the currenttransformer is located on the line side on both line end IEDs

• "Type 2" is selected on both ends when the secondary current directions forlocal and remote secondary is the same. "Type 2" should be used when the starpoint of the current transformer is located on the line side on one line end IEDand on the bus bar side on the other line end IED

Fail safe functionTo prevent malfunction during communication interference, the operation ofLNPLDF is blocked when the protection communication supervision detects severeinterference in the communication channel. The timer reset stage is activated incase the stabilized stage is started during a communication interruption.



GUID-010E1FF3-D7B0-42C8-9179-09F753D7DFC3 V1 EN

Figure 159: Operation logic of the fail safe function

The function can also be set into "Test/blocked" state with the Operation setting.This can also be utilized during the commissioning.

The BLOCK input is provided for blocking the function with the logic. When thefunction is blocked, the monitored data and measured values are still available butthe binary outputs are blocked. When the function is blocked, the direct inter-trip isalso blocked.

The PROT_ACTIVE output is always active when the protection function iscapable of operating. PROT_ACTIVE can be used as a blocking signal for backupprotection functions.

Stabilized low stageIn the stabilized low stage, the higher the load current increases, the higher thedifferential current required for tripping is. This happens on normal operation orduring external faults. When an internal fault occurs, the currents on both sides ofthe protected object flow towards the fault and cause the stabilizing current to beconsiderably lower. This makes the operation more sensitive during internal faults.The low stage includes a timer delay functionality.

The characteristic of the low stage taking the apparent differential current intoaccount is influenced by various factors:

• Small tapped loads within the protection zone• Current transformer errors• Current transformer saturation• Small asymmetry of the communication channel go and return paths• Small steady state line charging current.

The timer is activated according to the calculated differential, stabilizing currentand the set differential characteristic.



GUID-C5DA7D40-A17A-473F-A73D-6B291716C4A3 V1 EN

Figure 160: Operation logic of the stabilized low stage

The stabilization affects the operation of the function.

GUID-C7A3DFD3-1DDB-47EC-9C9A-B56FA4EDC69B V1 EN

Figure 161: Operating characteristics of the protection. (LS) stands for the lowstage and (HS) for the high stage.

The slope of the operating characteristic curve of the differential function varies inthe different sections of the range:



• Section 1 where 0.0 < Ib/In < End section 1. The differential current requiredfor tripping is constant. The value of the differential current is the same as thebasic setting (Low operate value) selected for the function. The basic settingallows the appearance of the no-load current of the line, the load current of thetapped load and minor inaccuracies of the current transformers. It can also beused to influence the overall level of the operating characteristic.

• Section 2 where End section 1 < Ib/In < End Section 2. This is called theinfluence area of the starting ratio. In this section, the variations in the startingratio affect the slope of the characteristic. That is, how big change is requiredfor tripping in the differential current in comparison with the change in theload current. The starting ratio should consider CT errors.

• Section 3 where End section 2 < Ib/In. By setting the slope in this section,attention can be paid to prevent unnecessary operation of the protection whenthere is an external fault, and the differential current is mainly produced bysaturated current transformers.

The operation of the differential protection is based on the fundamental frequencycomponents. The operation is accurate and stable and the DC component and theharmonics of the current do not cause unwanted operations.

TimerOnce activated, the timer activates the STR_LS_LOC output. Depending on thevalue of the set Operating curve type, the timer characteristics are according to DTor IDMT. When the operation timer has reached the value set with the Operatedelay time in the DT mode or the maximum value defined by the inverse timecurve, the OPR_LS_LOC output is activated. When the operation mode isaccording to IDMT, Low operate value is used as reference value (Start value) inthe IDMT equations presented in the Standard inverse-time characteristics section.

A timer reset state is activated when a drop-off situation happens. The reset isaccording to the DT characteristics.

For a detailed description of the timer characteristics, see theDirectional earth-fault characteristics section in this manual.

Instantaneous high stageIn addition to the stabilized low stage, LNPLDF has an instantaneous high stage.The stabilizing is not done with the instantaneous high stage. The instantaneoushigh stage operates immediately when the differential current amplitude is higherthan the set value of the High operate value setting. If the ENA_MULT_HS input isactive, the High operate value setting is internally multiplied by the High Op valueMult setting.



GUID-99000979-88BE-4A03-9F87-4A9608D91822 V1 EN

Figure 162: Operation logic of instantaneous high stage

Direct inter-tripDirect inter-trip is used to ensure the simultaneous opening of the circuit breakersat both ends of the protected line when a fault is detected. Both start and operatesignals are sent to the remote end via communication. The direct-intertripping ofthe line differential protection is included into LNPLDF. The OPERATE outputcombines the operate signals from both stages, local and remote, so that it can beused for the direct inter-trip signal locally.



STR_LS_LOC

STR_LS_REM

OPR_LS_LOC

OPR_LS_REM

OPR_HS_LOC

OPR_HS_REM

OPR_LS_A

OPR_LS_B

OPR_LS_CStabilizedlow stage

ORSEND

STR_LS_A

STR_LS_B

STR_LS_C

ORSEND

OPR_HS_A

OPR_HS_B

OPR_HS_C

ORSEND

OPR_LS_A

OPR_LS_B

OPR_LS_C

ORRECEIVE

STR_LS_A

STR_LS_B

STR_LS_C

ORRECEIVE

OPR_HS_A

OPR_HS_B

OPR_HS_C

ORRECEIVE

Inst.high stage

START

OPERATEOR

OR

GUID-002B4F83-260D-4ADA-983E-9CB46DBF1228 V3 EN

Figure 163: Operation logic of the direct intertrip function

The start and operate signals are provided separately for the low and high stages,and in local and remote.

Blocking functionalityThere are two independent inputs that can be used for blocking the function:BLOCK and BLOCK_LS. The difference between these inputs is that BLOCK_LS(when TRUE) blocks only the stabilized low stage leaving the instantaneous highstage operative. BLOCK (when TRUE) blocks both stages and also thePROT_ACTIVE output is updated according to the BLOCK input status, asdescribed in the Fail safe function chapter.

The BLOCK and BLOCK_LS input statuses affect only the behavior of the localprotection instance. When a line differential protection stage (stabilized low orinstantaneous high) is blocked, also the received remote signals related to the



corresponding stage are ignored (received direct inter-trip signals from the remoteend). The binary signal transfer functionality should therefore be used fortransferring the possible additional blocking information between the local andremote terminals whenever the blocking logic behavior needs to be the same onboth line ends.

Test mode

The line differential function in one IED can be set to test mode, that is, theOperation setting is set to “Test/blocked”. This blocks the line differentialprotection outputs in the IED and sets the remote IED to a remote test mode, suchthat the injected currents are echoed back with the shifted phase and settableamplitude. It is also possible that both IEDs are simultaneously in the test mode.When the line differential protection function is in the test mode:

• The remote end IED echoes locally injected current samples back with theshifted phase and settable amplitude.

• The operation of both stages (stabilized low or instantaneous high) areblocked, and also the direct inter-trip functionality is blocked (both receive andsend) in the IED where the test mode is active.

• The remote end line differential protection function that is in the normal mode(On) is not affected by the local end being in the test mode. This means thatthe remote end function is operative but, at the same time, it ignores thereceived current samples from the other end IED which is in the test mode.

• The PROT_ACTIVE output is false only in the IED that is currently in the testmode.

GUID-8E76712C-5DA3-46DA-AC6A-3C05CDBAB5AF V1 EN

Figure 164: Operation during the normal operation of the line differentialprotection



GUID-FC28C85A-6199-4249-8E01-C8693B005D3D V1 EN

Figure 165: Operation during test operation of the line differential protection

4.3.1.5 Commissioning

The commissioning of the line differential protection scheme would be difficultwithout any support features in the functionality because of the relatively longdistance between the IEDs. This has been taken into consideration in the design ofthe line differential protection. The communication channel can be used forechoing the locally fed current phasors from the remote end. By using this mode, itis possible to verify that differential calculation is done correctly in each phase.Also, the protection communication operation is taken into account with thedifferential current calculation when this test mode is used.

Required material for testing the IED

• Calculated settings• Terminal diagram• Circuit diagrams• Technical and application manuals of the IED• Single of three-phase secondary current source• Single phase primary current source• Timer with start and stop interfaces• Auxiliary voltage source for the IEDs• PC with related software, a web browser for web HMI

The setting and configuration of the IED must be completed before testing.

The terminal diagram, available in the technical manual, is a general diagram of theIED. Note, that the same diagram is not always applicable to each specific delivery,especially for the configuration of all the binary inputs and outputs. Therefore,before testing, check that the available terminal diagram corresponds to the IED.



Also, the circuit diagrams of the application are recommended to be available.Especially these are required for checking the terminal block numbers of thecurrent, trip, alarm and possibly other auxiliary circuits.

The technical and application manuals contain application and functionalitysummaries, function blocks, logic diagrams, input and output signals, settingparameters and technical data sorted per function.

The minimum requirement for a secondary current injection test device is theability to work as a one phase current source.

Prepare the IED for the test before testing a particular function. Consider the logicdiagram of the tested protection function when performing the test. All includedfunctions in the IED are tested according to the corresponding test instructions inthis chapter. The functions can be tested in any order according to user preferences.Therefore, the test instructions are presented in alphabetical order. Only thefunctions that are in use (Operation is set to "On") should be tested.

The response from the test can be viewed in different ways:

• Binary output signals• Monitored data values in the local HMI (logical signals)• A PC with a web browser for web HMI use (logical signals and phasors).

All used setting groups should be tested.

Checking the external optical and electrical connectionsThe user must check the installation to verify that the IED is connected to the otherrequired parts of the protection system. The IED and all the connected circuits areto be de-energized during the check-up.

Checking the CT circuits

Check that the wiring is in strict accordance with the suppliedconnection diagram.

The CTs must be connected in accordance with the terminal diagram provided withthe IED, both with regards to phases and polarity. The following tests arerecommended for every primary CT or CT core connected to the IED.

• Primary injection test to verify the current ratio of the CT, the correct wiringup to the protection IED and correct phase sequence connection (that is L1,L2, L3.)

• Polarity check to prove that the predicted direction of the secondary currentflow is correct for a given direction of the primary current flow. This is anessential test for the proper operation of the directional function, protection ormeasurement in the IED.

• CT secondary loop resistance measurement to confirm that the currenttransformer secondary loop DC resistance is within specification and that thereare no high resistance joints in the CT winding or wiring.



• CT excitation test to ensure that the correct core in the CT is connected to theIED. Normally only a few points along the excitation curve are checked toensure that there are no wiring errors in the system, for example, due to amistake in connecting the CT's measurement core to the IED.

• CT excitation test to ensure that the CT is of the correct accuracy rating andthat there are no short circuited turns in the CT windings. Manufacturer'sdesign curves should be available for the CT to compare the actual results.

• Earthing check of the individual CT secondary circuits to verify that each three-phase set of main CTs is properly connected to the station earth and only atone electrical point.

• Insulation resistance check.• Phase identification of CT shall be made.

Both the primary and the secondary sides must be disconnectedfrom the line and the IED when plotting the excitation characteristics.

If the CT secondary circuit is opened or its earth connection ismissing or removed without the CT primary being de-energizedfirst, dangerous voltages may be produced. This can be lethal andcause damage to the insulation. The re-energizing of the CTprimary should be prohibited as long as the CT secondary is openor unearthed."

Checking of the power supplyCheck that the auxiliary supply voltage remains within the permissible inputvoltage range under all operating conditions. Check that the polarity is correctbefore powering the IED.

Checking binary I/O circuitsAlways check the binary input circuits from the equipment to the IED interface tomake sure that all signals are connected correctly. If there is no need to test aparticular input, the corresponding wiring can be disconnected from the terminal ofthe IED during testing. Check all the connected signals so that both input voltagelevel and polarity are in accordance with the IED specifications. However,attention must be paid to the electrical safety instructions.

Always check the binary output circuits from the IED to the equipment interface tomake sure that all signals are connected correctly. If a particular output needs to betested, the corresponding wiring can be disconnected from the terminal of the IEDduring testing. Check all the connected signals so that both load and polarity are inaccordance with the IED specifications. However, attention must be paid to theelectrical safety instructions.

Checking optical connectionsCheck that the Tx and Rx optical connections are correct.



An IED equipped with optical connections requires a minimumdepth of 180 mm for plastic fiber cables and 275 mm for glass fibercables. Check the allowed minimum bending radius from theoptical cable manufacturer.

Applying required settings for the IEDDownload all calculated settings and measurement transformer parameters in theIED.

Connecting test equipment to the IEDBefore testing, connect the test equipment according to the IED specific connectiondiagram.

Pay attention to the correct connection of the input and output current terminals.Check that the input and output logical signals in the logic diagram for the functionunder test are connected to the corresponding binary inputs and outputs of the IED.Also, pay attention to selecting the correct auxiliary voltage source according to thepower supply module of the IED. Also, pay attention to selecting the correctauxiliary voltage source according to the power supply module of the IED.



GUID-F1F4E199-8B6A-4066-ACCB-07FE4F887417 V1 EN

Figure 166: Example of connections to test the line differential IED

Secondary current injectionThere are two alternative modes to check the operation of a line differential IED.These are not exclusive methods for each other and can be used for various test onthe IED.

Normal modeIn normal mode, that is, the mode when the function is on normal operation, thelocal end IED sends phasors to the remote end IED and receives phasors measuredby the remote end IED. This mode can be used in testing the operating level andtime of the low and high stages of the local end IED. This is due to a test situationwhen the remote end does not measure any current and therefore, all the current fedto the local end current circuit is seen as differential current at both ends.

Testing of the line differential protection is done with both IEDs separatedgeographically from each other. It is important to note that local actions in one IEDcause operation also in the remotely located IED. When testing the line differentialfunction, actions have to be done in both IEDs.



Before the test, the trip signal to the circuit breaker shall be blocked, for exampleby breaking the trip circuit by opening the terminal block or by using some othersuitable method.

When injecting current to one phase in the local end IED, the current is seen as adifferential current at both ends. If a current Iinjected is injected, L1 in phase L1, thedifferential and stabilizing currents for phase L1 are:

IDIFF A IBIAS A Iinjected_ _= × =2

GUID-B5B84B9B-B26C-421F-B4D0-E301EE4883F3 V2 EN (Equation 31)

The operation is equal for phases L2 and L3.

Verifying the settingsProcedure

1. Block the unwanted trip signals from the IED units involved.2. Inject a current in phase L1 and increase the current until the function

operates for phase L1.The injected operate current shall correspond to the set Low operate value.The monitored values for IDIFF_A and IBIAS_A should be equal to theinjected current.

3. Repeat point 2 by current injection in phases L2 and L3.4. Measure the operating time by injecting the single-phase current in phase 1.

The injected current should be four times the operating current. The timemeasurement is stopped by the trip output from the IED unit.

5. Disconnect the test equipment and reconnect the current transformers and allother circuits including the trip circuit.

Phasor echoing methodThe line differential function in one IED can be set to special test mode, that is, theOperation setting is set to “Test/blocked”. When this mode is in use, the remoteend IED echoes locally injected current phasors back with the shifted phase andsettable amplitude. The local end line differential function is also automaticallyblocked during this and the remote end line differential function discards thephasors it receives from the IED that is in the test mode

When the test mode is active, the CT connection type and CT ratio correctionsetting parameter values are still used by the line differential protection function asin the normal operation mode. These can be used for shifting the phase (0 or 180degrees) and setting the amplitude of the echoed back phasors. For example, ifthree phase currents are injected to the local end IED which is also set to the testmode, the selected CT connection type is "Type 2" and the CT ratio correctionsetting parameter value is 0.500.



GUID-6F26D761-CB1D-4D86-80AA-CEC95CEBC1A9 V1 EN

Figure 167: An example of a test mode situation where three phase currentsare injected to the local end IED

GUID-21BCDEC5-2A22-4AEE-831E-BC8A72E40A64 V1 EN

Figure 168: Local and remote end currents presented in a web HMI of the IED

4.3.1.6 Application

LNPLDF is designed for the differential protection of overhead line and cablefeeders in a distribution network. LNPLDF provides absolute selectivity and fastoperating times as unit protection also in short lines where distance protectioncannot be applied.



LNPLDF provides selective protection for radial, looped and meshed networktopologies and can be used in isolated neutral networks, resistance earthednetworks, compensated (impedance earthed) networks and solidly earthednetworks. In a typical network configuration where the line differential protectionscheme is applied, the protected zone, that is, the line or cable, is fed from twodirections.

GUID-E9D80758-16A2-4748-A08C-94C33997E603 V1 EN

Figure 169: Line protection with phase segregated line differential IEDs

LNPLDF can be utilized for various types of network configurations or topologies.Case A shows the protection of a ring-type distribution network. The network isalso used in the closed ring mode. LNPLDF is used as the main protection fordifferent sections of the feeder. In case B, the interconnection of two substations isdone with parallel lines and each line is protected with the line differentialprotection. In case C, the connection line to mid scale power generation (typicalsize around 10 - 50MVA) is protected with the line differential function. In case D,the connection between two substations and a small distribution transformer islocated at the tapped load. The usage of LNPLDF is not limited to these applications.



GUID-64A6AADE-275F-43DA-B7D9-2B1340166A4D V1 EN

Figure 170: Line differential applications

Communication supervisionA typical line differential protection application includes LNPLDF as mainprotection. Backup over current functions are needed in case of a protectioncommunication failure. When the communication supervision function detects afailure in the communication between the protective units, the safe operation of theline is still guaranteed by blocking the line differential protection and unblockingthe over current functions.

When a communication failure is detected, the protection communicationsupervision function issues block for the LNPLDF line differential protection andunblock for the instantaneous and high stages (instance 2) of the over currentprotection. These are used to give backup protection for the remote end feederprotection IED. Although there can be a situation where the selectivity is weakerthan usually, the protection should still be available for the system.



GUID-01A2A41E-2813-448D-953F-F9690578DEDE V1 EN

Figure 171: Protection communication supervision detects failures oncommunication

Small power transformers in a tapWith a relatively small power transformer in a line tap, the line differentialprotection can be applied without the need of current measurement from the tap. Insuch cases, the line differential function is time delayed for low differentialcurrents below the high set limit and LNPLDF coordinates with the downstreamIEDs in the relevant tap. For differential currents above the set limit, the operationis instantaneous. As a consequence, when the load current of the tap is negligible,the low resistive line faults are cleared instantaneously at the same time asmaximum sensitivity for the high resistive faults are maintained but with a timedelayed operation.



GUID-F1B36FF9-7463-4D8D-8EDC-70A09B52CAE9 V1 EN

Figure 172: Influence of the tapped transformer load current to the stabilizedlow stage setting

The stabilized stage provides both DT and IDMT characteristics that are used toprovide time selective protection against faults external to the instantaneous stagecoverage. The impedance of the line is typically an order of magnitude lower thanthe transformer impedance providing significantly higher fault currents when thefault is located on the line.

GUID-F9600D18-75B9-4EA5-8F9B-656FCB1FC938 V1 EN

Figure 173: Influence of the short circuit current at LV side of the tappedtransformer to the differential current



Detection of the inrush current during transformer start-upWhen the line is energized, the transformer magnetization inrush current is seen asdifferential current by the line differential protection and may cause malfunction ofthe protection if not taken into account. The inrush situation may only be detectedon one end but the differential current is always seen on both ends. The inrushcurrent includes high order harmonic components which can be detected and usedas the blocking criteria for the stabilized stage. The inrush detection information ischanged between two ends so that fast and safe blocking of the stabilized stage canbe issued on both ends.

GUID-0383F2EF-18CC-45A0-A9BC-E04658981495 V1 EN

Figure 174: Blocking of line differential functions during detected transformerstartup current

If the protection stage is allowed to start during the inrush situation, the time delaycan be selected in such a way that the stabilized stage does not operate in the inrushsituation.

4.3.1.7 Signals

Table 297: LNPLDF Input signals

Name Type Default DescriptionI_LOC_A SIGNAL 0 Phase A local current

I_LOC_B SIGNAL 0 Phase B local current

I_LOC_C SIGNAL 0 Phase C local current

I_REM_A SIGNAL 0 Phase A remote current




Name Type Default DescriptionI_REM_B SIGNAL 0 Phase B remote current

I_REM_C SIGNAL 0 Phase C remote current

BLOCK BOOLEAN 0=False Signal for blocking the function

BLOCK_LS BOOLEAN 0=False Signal for blocking the stab. stage

ENA_MULT_HS BOOLEAN 0=False Enables the high stage multiplier

Table 298: LNPLDF Output signals

Name Type DescriptionOPERATE BOOLEAN Operate, local or remote, stabilized or

instantaneous stage

START BOOLEAN Start, local or remote

STR_LS_LOC BOOLEAN Start stabilized stage local

STR_LS_REM BOOLEAN Start stabilized stage remote

OPR_LS_LOC BOOLEAN Operate stabilized stage local

OPR_LS_REM BOOLEAN Operate stabilized stage remote

OPR_HS_LOC BOOLEAN Operate instantaneous stage local

OPR_HS_REM BOOLEAN Operate instantaneous stage remote

RSTD2H_LOC BOOLEAN Restraint due 2nd harmonics detected local

RSTD2H_REM BOOLEAN Restraint due 2nd harmonics detected remote

PROT_ACTIVE BOOLEAN Status of the protection, true when function isoperative

4.3.1.8 Settings

Table 299: LNPLDF Group settings

Parameter Values (Range) Unit Step Default DescriptionHigh operate value 200...4000 %In 1 2000 Instantaneous stage operate value

High Op value Mult 0.5...1.0 0.1 1.0 Multiplier for scaling the high stageoperate value

Low operate value 10...200 %In 1 10 Basic setting for the stabilized stage start

End section 1 0...200 %In 1 100 Turn-point between the first and thesecond line of the operatingcharacteristics

Slope section 2 10...50 % 1 50 Slope of the second line of the operatingcharacteristics

End section 2 200...2000 %In 1 500 Turn-point between the second and thethird line of the operating characteristics

Slope section 3 100...200 % 1 150 Slope of the third line of the operatingcharacteristics

Operate delay time 45...200000 ms 1 45 Operate delay time for stabilized stage




Parameter Values (Range) Unit Step Default DescriptionOperating curve type 1=ANSI Ext. inv.

3=ANSI Norm. inv.5=ANSI Def. Time9=IEC Norm. inv.10=IEC Very inv.12=IEC Ext. inv.15=IEC Def. Time

15=IEC Def. Time Selection of time delay curve forstabilized stage

Time multiplier 0.05...15.00 0.01 1.00 Time multiplier in IDMT curves

Start value 2.H 10...50 % 1 20 The ratio of the 2. harmonic componentto fundamental component required forblocking

Table 300: LNPLDF Non group settings


4=test/blocked5=off

1=on Operation mode of the function

Restraint mode 1=None2=Harmonic2

1=None Selects what restraint modes are in use

Reset delay time 0...60000 ms 1 0 Reset delay time for stabilized stage

Minimum operate time 45...60000 ms 1 45 Minimum operate time for stabilizedstage IDMT curves

CT ratio correction 0.200...5.000 0.001 1.000 Remote phase current transformer ratiocorrection

CT connection type 1=Type 12=Type 2

1=Type 1 CT connection type. Determined by thedirections of the connected currenttransformers.

4.3.1.9 Monitored Data

Table 301: LNPLDF Monitored data

Name Type Values (Range) Unit DescriptionI_INST_LOC_A FLOAT32 0.00...40.00 xIn Local phase A Amplitude

I_INST_LOC_B FLOAT32 0.00...40.00 xIn Local phase B Amplitude

I_INST_LOC_C FLOAT32 0.00...40.00 xIn Local phase C Amplitude

I_INST_REM_A FLOAT32 0.00...40.00 xIn Remote phase AAmplitude aftercorrection

I_INST_REM_B FLOAT32 0.00...40.00 xIn Remote phase BAmplitude aftercorrection

I_INST_REM_C FLOAT32 0.00...40.00 xIn Remote phase CAmplitude aftercorrection

IDIFF_A FLOAT32 0.00...80.00 xIn Differential currentphase A

IDIFF_B FLOAT32 0.00...80.00 xIn Differential currentphase B




Name Type Values (Range) Unit DescriptionIDIFF_C FLOAT32 0.00...80.00 xIn Differential current

phase C

IBIAS_A FLOAT32 0.00...80.00 xIn Stabilization currentphase A

IBIAS_B FLOAT32 0.00...80.00 xIn Stabilization currentphase B

IBIAS_C FLOAT32 0.00...80.00 xIn Stabilization currentphase C

I_ANGL_DIFF_A FLOAT32 -180.00...180.00 deg Current phase angledifferential between localand remote, phase A

I_ANGL_DIFF_B FLOAT32 -180.00...180.00 deg Current phase angledifferential between localand remote, phase B

I_ANGL_DIFF_C FLOAT32 -180.00...180.00 deg Current phase angledifferential between localand remote, phase C


LNPLDF Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 302: LNPLDF Technical data

Characteristics ValueOperation accuracy 1) Depending on the frequency of the current

measured: fn ±2 Hz

Low stage ±2.5% of the set value

High stage ±2.5% of the set value

Minimum Typical Maximum

High stage, operate time 2)3) 22 ms 25 ms 29 ms

Reset time < 40 ms


Retardation time (Low stage) < 40 ms


Operate time accuracy in inverse time mode ±5.0% of the set value or ±20 ms 4)

1) With the symmetrical communication channel (as when using dedicated fiber optic).2) Without additional delay in the communication channel (as when using dedicated fiber optic).3) Including the delay of the output contact. When differential current = 2 x High operate value and fn =

50 Hz with galvanic pilot wire link + 5 ms.4) Low operate value multiples in range of 1.5 to 20.




Table 303: LNPLDF Technical revision history

Technical revision ChangeB Step value changed from 0.05 to 0.01 for the

Time multiplier setting.

4.3.2 Stabilized and instantaneous differential protection for 2W-transformers TR2PTDF





Stabilized and instantaneousdifferential protection for 2W-transformers

TR2PTDF 3dI>T 87T


GUID-134E8524-738D-4232-A6BD-4C9BD2A62F8D V1 EN



The transformer differential protection TR2PTDF is designed to protect two-winding transformers and generator-transformer blocks. TR2PTDF includes lowbiased and high instantaneous stages.

The biased low stage provides a fast clearance of faults while remaining stable withhigh currents passing through the protected zone increasing errors on currentmeasuring. The second harmonic restraint, together with the waveform basedalgorithms, ensures that the low stage does not operate due to the transformerinrush currents. The fifth harmonic restraint ensures that the low stage does notoperate on apparent differential current caused by a harmless transformer over-excitation.

The instantaneous high stage provides a very fast clearance of severe faults with ahigh differential current regardless of their harmonics.



The setting characteristic can be set more sensitive with the aid of tap changerposition compensation. The correction of transformation ratio due to the changes intap position is done automatically based on the tap changer status information.



The operation of transformer differential protection can be described by using amodule diagram. All the modules in the diagram are explained in the next sections.

GUID-3A506E19-4E77-4866-8EDC-6264823E1090 V1 EN

Figure 176: Functional module diagram. I_x1 and I_x2 represent the phasecurrents of winding 1 and winding 2

Differential calculationTR2PTDF operates phase-wise on a difference of incoming and outgoing currents.The positive direction of the currents is towards the protected object.



Winding 1(usually HV)

Winding 2(usually LV)

1WI 2WI

GUID-DABAB343-214F-4A86-ADC8-BFD8E64B25A7 V3 EN

Figure 177: Positive direction of the currents

I I Id W W= +1 2

GUID-0B35503B-CA7D-4598-A1E4-59C9AA66012D V2 EN (Equation 32)

In a normal situation, no fault occurs in the area protected by TR2PTDF. Then thecurrents IW1 and IW 2 are equal and the differential current Id is zero. In practice,however, the differential current deviates from zero in normal situations. In thepower transformer protection, the differential current is caused by CT inaccuracies,variations in tap changer position (if not compensated), transformer no-load currentand instantaneous transformer inrush currents. An increase in the load currentcauses the differential current, caused by the CT inaccuracies and the tap changerposition, to grow at the same percentage rate.

In a biased differential IED in normal operation or during external faults, the higherthe load current is the higher is the differential current required for tripping. Whenan internal fault occurs, the currents on both sides of the protected object areflowing into it. This causes the biasing current to be considerably smaller, whichmakes the operation more sensitive during internal faults.

I

I I

b

W W

=

−1 2

2

GUID-1403DDDA-D840-4746-A925-F426AC7A8608 V2 EN (Equation 33)

If the biasing current is small compared to the differential current or if the phaseangle between the winding 1 and winding 2 phase currents is close to zero (in anormal situation, the phase difference is 180 degrees), a fault has most certainlyoccurred in the area protected by the differential IED. Then the operation value setfor the instantaneous stage is automatically halved and the internal blocking signalsof the biased stage are inhibited.

Transformer vector group matchingThe phase difference of the winding 1 and winding 2 currents that is caused by thevector group of the power transformer is numerically compensated. The matchingof the phase difference is based on the phase shifting and the numerical deltaconnection inside the IED. The Winding 2 type parameter determines theconnections of the phase windings on the low voltage side(“y”, ”yn”, ”d”, ”z”, ”zn”). Similarly, the Winding 1 type parameter determines theconnection on winding 1 (”Y”, ”YN”, ”D”, ”Z”, ”ZN”).



The vector group matching can be implemented either on both, winding 1 andwinding 2, or only on winding 1 or winding 2, at intervals of 30° with the Clocknumber setting.

When the vector group matching is Yy0 and the CT connection type is according to"Type 2", the phase angle of the phase currents connected to the IED does notchange. When the vector group matching is Yy6, the phase currents are turned180° in the IED.

Example 1Vector group matching of a Ynd11-connected power transformer on winding 1, CTconnection type according to type 1. The Winding 1 type setting is ”YN”, Winding2 type is “d” and Clock number is “Clk Num 11”. This is compensated internallyby giving winding 1 internal compensation value +30° and winding 2 internalcompensation value 0°:

II I

II I

II I

L mHV

L L

L mHV

L L

L mHV

L L

11 2

22 3

33 1

3

3

3

=−

=−

=−

GUID-633921A4-D973-4BD2-BFDF-E9FF73C3B9E3 V1 EN (Equation 34)

Example 2But if vector group is Yd11 and CT connection type is according to type 1, thecompensation is a little different. The Winding 1 type setting is ”Y”, Winding 2type is “d” and Clock number is “Clk Num 11”. This is compensated internally bygiving winding 1 internal compensation value 0° and winding 2 internalcompensation value -30°;

II I

II I

II I

L mLVL L

L mLVL L

L mLVL L

11 3

22 1

33 2

3

3

3

=−

=−

=−

GUID-41089920-D9BF-4574-96FB-0B1F48019391 V1 EN (Equation 35)

The "Y" side currents stay untouched, while the "d" side currents are compensatedto match the currents actually flowing in the windings.

In this example there is no neutral current on either side of the transformer(assuming there are no earthing transformers installed). In the previous example,however, the matching is done differently to have the winding 1 neutral currentcompensated at the same time.



Zero-sequence component eliminationIf Clock number is "Clk Num 2", "Clk Num 4", "Clk Num 8" or "Clk Num 10", thevector group matching is always done on both, winding 1 and winding 2. Thecombination results in the correct compensation. In this case the zero-sequencecomponent is always removed from both sides automatically. The Zro Aelimination parameter cannot change this.

If Clock number is "Clk Num 1", "Clk Num 5", "Clk Num 7" or "Clk Num 11", thevector group matching is done on one side only. A possible zero-sequencecomponent of the phase currents at earth faults occurring outside the protectionarea is eliminated in the numerically implemented delta connection before thedifferential current and the biasing current are calculated. This is why the vectorgroup matching is almost always made on the star connected side of the "Ynd" and"Dyn" connected transformers.

If Clock number is "Clk Num 0" or "Clk Num 6", the zero-sequence component ofthe phase currents is not eliminated automatically on either side. Therefore, the zero-sequence component on the star connected side that is earthed at its star point hasto be eliminated by using the Zro A elimination parameter.

The same parameter has to be used to eliminate the zero-sequence component ifthere is, for example, an earthing transformer on the delta-connected side of the"Ynd" power transformer in the area to be protected. In this case, the vector groupmatching is normally made on the side of the star connection. On the side of thedelta connection, the elimination of the zero-sequence component has to beseparately selected.

By using the Zro A elimination parameter, the zero-sequence component of thephase currents is calculated and reduced for each phase current:

I I x I I I

I I x I I I

I I

L m L L L L

L m L L L L

L m L

1 1 1 2 3

2 2 1 2 3

3 3

1

3

1

3

= − + +( )

= − + +( )

= −− + +( )1

31 2 3x I I IL L L

GUID-398EDAFF-4A32-4C39-AD75-1F6D19B8FF48 V1 EN (Equation 36)

In many cases with the earthed neutral of a "wye" winding, it ispossible to make the compensation so that a zero-sequencecomponent of the phase currents is automatically eliminated. Forexample, in a case of a "Ynd" transformer, the compensation ismade on the winding 1 side to automatically eliminate the zero-sequence component of the phase currents on that side (and the "d"side does not have them). In those cases, explicit elimination is notneeded.



Compensation of tap changer positionThe position of the tap changer used for voltage control can be compensated andthe position information is provided for the protection function through the tapposition indication function TPOSSLTC1.

Typically, the tap changer is located within the high voltage winding, that is,winding 1, of the power transformer. The Tapped winding parameter specifieswhether the tap changer is connected to the high voltage side winding or the lowvoltage side winding. This parameter is also used to enable and disable theautomatic adaptation to the tap changer position. The possible values are "Not inuse", "Winding 1", "Winding 2".

The Tap nominal parameter tells the number of the tap, which results in thenominal voltage (and current). When the current tap position deviates from thisvalue, the input current values on the side where the tap changer resides are scaledto match the currents on the other side.

A correct scaling is determined by the number of steps and the direction of thedeviation from the nominal tap and the percentage change in voltage resulting froma deviation of one tap step. The percentage value is set using the Step of tap parameter.

The operating range of the tap changer is defined by the Min winding tap and Maxwinding tap parameters. The Min winding tap parameter tells the tap positionnumber resulting in the minimum effective number of winding turns on the side ofthe transformer where the tap changer is connected. Correspondingly, the Maxwinding tap parameter tells the tap position number resulting in the maximumeffective number of winding turns.

The Min winding tap and Max winding tap parameters help the tap positioncompensation algorithm know in which direction the compensation is being made.This ensures also that if the current tap position information is corrupted for somereason, the automatic tap changer position adaptation does not try to adapt to anyunrealistic position values.

GUID-317C68F8-A517-458A-A5D0-32FCE6C5F547 V1 EN

Figure 178: Simplified presentation of the high voltage and medium voltagewindings with demonstration of the Max winding tap, Min windingtap and Tap nominal parameters



The position value is available through the Monitored data view on LHMI orthrough other communication tools in the tap position indication function. Whenthe quality of the TAP_POS value is not good, the position information inTAP_POS is not used but the last value with the good quality information is usedinstead. In addition, the minimum sensitivity of the biased stage, set by the Lowoperate value setting, is automatically desensitized with the total range of the tapposition correction. The new acting low operate value is

Desensitized Low operate value = Lowoperatevalue ABS MaxWi+ ( nnding tap Min winding tap Step of tap− ×)

GUID-2E5AD399-D8DD-4F64-A194-7540D55DB8ED V3 EN (Equation 37)

Second harmonic blockingThe transformer magnetizing inrush currents occur when energizing thetransformer after a period of de-energization. The inrush current can be many timesthe rated current and the halving time can be up to several seconds. To thedifferential protection, the inrush current represents a differential current, whichwould cause the differential protection to operate almost always when thetransformer is connected to the network. Typically, the inrush current contains alarge amount of second harmonics.

Blocking the operation of the TR2PTDF biased low stage at a magnetizing inrushcurrent is based on the ratio of the amplitudes of the second harmonic digitallyfiltered from the differential current and the fundamental frequency (Id2f /Id1f).

The blocking also prevents unwanted operation at the recovery and sympatheticmagnetizing inrushes. At the recovery inrush, the magnetizing current of thetransformer to be protected increases momentarily when the voltage returns tonormal after the clearance of a fault outside the protected area. The sympatheticinrush is caused by the energization of another transformer running in parallel withthe protected transformer already connected to the network.

The ratio of the second harmonic to a fundamental component can varyconsiderably between the phases. Especially when the delta compensation is donefor a Ynd1 connected transformer and the two phases of the inrush currents areotherwise equal but opposite in phase angle, the subtraction of the phases in a deltacompensation results in a very small second harmonic component.

Some measures have to be taken in order to avoid the false tripping of a phasehaving too low a ratio of the second harmonic to the fundamental component. Oneway could be to always block all the phases when the second harmonic blockingconditions are fulfilled in at least one phase. The other way is to calculate theweighted ratios of the second harmonic to the fundamental component for eachphase using the original ratios of the phases. The latter option is used here. Thesecond harmonic ratios I_2H_RAT_x are given in monitored data.

The ratio to be used for second harmonic blocking is, therefore, calculated as aweighted average on the basis of the ratios calculated from the differential currentsof the three phases. The ratio of the concerned phase is of most weight compared tothe ratios of the other two phases. In this IED, if the weighting factors are four, oneand one, four is the factor of the phase concerned. The operation of the biased stage



on the concerned phase is blocked if the weighted ratio of that phase is above theset blocking limit Start value 2.H and if blocking is enabled through the Restraintmode parameter.

Using separate blocking for the individual phases and weighted averages calculatedfor the separate phases provides a blocking scheme that is stable at the connectioninrush currents.

If the peak value of the differential current is very high, that is Ir> 12 xIn, the limitfor the second harmonic blocking is desensitized (in the phase in question) byincreasing it proportionally to the peak value of the differential current.

The connection of the power transformer against a fault inside the protected areadoes not delay the operation of the tripping, because in such a situation theblocking based on the second harmonic of the differential current is prevented by aseparate algorithm based on a different waveform and a different rate of change ofthe normal inrush current and the inrush current containing the fault current. Thealgorithm does not eliminate the blocking at inrush currents, unless there is a faultin the protected area.

The feature can also be enabled and disabled with the Harmonic deblock 2.Hparameter.

Fifth harmonic blockingThe inhibition of TR2PTDF operation in the situations of overexcitation is basedon the ratio of the fifth harmonic and the fundamental component of the differentialcurrent (Id5f/Id1f). The ratio is calculated separately for each phase withoutweighting . If the ratio exceeds the setting value of Start value 5.H and if blockingis enabled through the Restraint mode parameter, the operation of the biased stageof TR2PTDF in the concerned phase is blocked.The fifth harmonic ratiosI_5H_RAT_x are given in monitored data.

At dangerous levels of overvoltage, which can cause damage to the transformer,the blocking can be automatically eliminated. If the ratio of the fifth harmonic andthe fundamental component of the differential current exceeds the Stop value 5.Hparameter, the blocking removal is enabled. The enabling and disabling ofdeblocking feature is also done through the Harmonic deblock 5.H parameter.



GUID-A97464D1-3085-4F27-B829-11EEC47CA654 V1 EN

Figure 179: The limits and operation of the fifth harmonic blocking when bothblocking and deblocking features are enabled using the Harmonicdeblock 5.H control parameter.

The fifth harmonic blocking has a hysteresis to avoid rapid fluctuation between"TRUE" and "FALSE". The blocking also has a counter, which counts the requiredconsecutive fulfillments of the condition. When the condition is not fulfilled, thecounter is decreased (if >0).

Also the fifth harmonic deblocking has a hysteresis and a counter which counts therequired consecutive fulfillments of the condition. When the condition is notfulfilled, the counter is decreased (if >0).

Waveform blockingThe biased low stage can always be blocked with waveform blocking. The stagecan not be disabled with the Restraint mode parameter. This algorithm has twoparts. The first part is intended for external faults while the second is intended forinrush situations. The algorithm has criteria for a low current period during inrushwhere also the differential current (not derivative) is checked.

Biased low stageThe current differential protection needs to be biased because the possibleappearance of a differential current can be due to something else than an actualfault in the transformer (or generator).

In the case of transformer protection, a false differential current can be caused by:

• CT errors• Varying tap changer positions (if not automatically compensated)• Transformer no-load current• Transformer inrush currents• Transformer overexcitation in overvoltage• Underfrequency situations• CT saturation at high currents passing through the transformer.



The differential current caused by CT errors or tap changer positions increases atthe same percent ratio as the load current.

In the protection of generators, the false differential current can be caused by:

• CT errors• CT saturation at high currents passing through the generator.

OPERATE

OPR_LS

BLKD2HPHAR_A(from Second harmonic blocking)

BLKD2HPHAR_C(from Second harmonic blocking)

BLKD2HPHAR_A(from Second harmonic blocking)

Fault in protected area(from Differential calculation)

BLKD5HPHAR_A(from Fifth harmonic blocking)

BLKD5HPHAR_C(from Fifth harmonic blocking)

BLKD5HPHAR_B(from Fifth harmonic blocking)

BLKDWAV_A(from Waveform blocking)

BLKDWAV_B(from Waveform blocking)

BLKDWAV_C(from Waveform blocking))

AND

AND

AND

AND

AND

AND

AND

AND

AND

AND

AND

AND

AND

AND

AND

AND

AND

AND

BLKD2H

BLKD5H

BLKDWAV

OR

OR

OR

OR

OR

OR

I

Charact.

Ibias

I_D(from Differential calculation)

I_B(from Differential calculation)

BLOCK

BLOCK_OPR_LS AND

AND

AND

OR

Low operate value

Slope section 2

End section 2

GUID-0E927DF9-5641-4CAE-B808-0B75EA09EA95 V2 EN

Figure 180: Operation logic of the biased low stage

The high currents passing through a protected object can be caused by the shortcircuits outside the protected area, the large currents fed by the transformer inmotor startup or the transformer inrush situations. Therefore, the operation of thedifferential protection is biased in respect to the load current. In biased differentialprotection, the higher the differential current required for the protection to operate,the higher the load current.

The operating characteristic of the biased low stage is determined by Low operatevalue, Slope section 2 and the setting of the second turning point of the operatingcharacteristic curve, End section 2 (the first turning point and the slope of the lastpart of the characteristic are fixed). The settings are the same for all the phases.When the differential current exceeds the operating value determined by the



operating characteristic, the differential function awakes. If the differential currentstays above the operating value continuously for a suitable period, which is 1.1times the fundamental cycle, the OPR_LS output is activated. The OPERATEoutput is always activated when the OPR_LS output is activated.

The stage can be blocked internally by the second or fifth harmonic restraint, or byspecial algorithms detecting inrush and current transformer saturation at externalfaults. When the operation of the biased low stage is blocked by the secondharmonic blocking functionality, the BLKD2H output is activated.

When operation of the biased low stage is blocked by the fifth harmonic blockingfunctionality, the BLKD5H output is activated. Correspondingly, when theoperation of the biased low stage is blocked by the waveform blockingfunctionality, the BLKDWAV output is activated according to the phase information.

When required, the operate outputs of the biased low stage can be blocked by theBLK_OPR_LS or BLOCK external control signals.

Ib2

Id1

Id2

Ib3

Id3

100

200

300

100 200 300 400 500

End section 2End section 1

Low operate value

Section 1 Section 2 Section 3

Id [%Ir]

Ib [%Ir]

GUID-EAAB6851-B6A9-4A69-B962-1725A4928D54 V3 EN

Figure 181: Operation characteristic for biased operation of TR2PTDF

The Low operate value of the biased stage of the differential function is determinedaccording to the operation characteristic:

Low operate value = Id1

Slope section 2 is determined correspondingly:

Slope section Id Ib2 2 2 100= ×/ %

GUID-D1C2CAED-3D58-4405-A79D-17B203A8D3A9 V3 EN (Equation 38)



The second turning point End section 2 can be set in the range of 100 percent to500 percent.

The slope of the differential function's operating characteristic curve varies in thedifferent sections of the range.

• In section 1, where 0 percent Ir < Ib < End section 1, End section 1 being fixedto 50 percent Ir, the differential current required for tripping is constant. Thevalue of the differential current is the same as the Low operate value selectedfor the function. Low operate value basically allows the no-load current of thepower transformer and small inaccuracies of the current transformers, but itcan also be used to influence the overall level of the operating characteristic.At the rated current, the no-load losses of the power transformer are about 0.2percent. If the supply voltage of the power transformer suddenly increases dueto operational disturbances, the magnetizing current of the transformerincreases as well. In general the magnetic flux density of the transformer israther high at rated voltage and a rise in voltage by a few percent causes themagnetizing current to increase by tens of percent. This should be consideredin Low operate value

• In section 2, where End section 1 < Ib/In < End section 2, is called theinfluence area of Slope section 2. In this section, variations in the starting ratioaffect the slope of the characteristic, that is, how big a change in thedifferential current is required for tripping in comparison with the change inthe load current. The starting ratio should consider CT errors and variations inthe transformer tap changer position (if not compensated). Too high a startingratio should be avoided, because the sensitivity of the protection for detectinginter-turn faults depends basically on the starting ratio.

• In section 3, where Ib/In > End section 2, the slope of the characteristic isconstant. The slope is 100%, which means that the increase in the differentialcurrent is equal to the corresponding increase in the biasing current.



GUID-739E1789-778D-44BF-BD4A-6BD684BF041D V2 EN

Figure 182: Setting range for biased low stage

If the biasing current is small compared to the differential current of the phaseangle between the winding 1 and winding 2 phase currents is close to zero (in anormal situation, the phase difference is 180 degrees), a fault has most likelyoccurred in the area protected by TR2PTDF. Then the internal blocking signals ofthe biased stage are inhibited.

Instantaneous high stageThe instantaneous high stage operation can be enabled and disabled with theEnable high set setting. The corresponding parameter values are "TRUE" and"FALSE."

The operation of the instantaneous high stage is not biased. The instantaneous stageoperates and the output OPR_HS is activated when the amplitude of thefundamental frequency component of the differential current exceeds the set Highoperate value or when the instantaneous value of the differential current exceeds2.5 times the value of High operate value. The factor 2.5 (=1.8 x √2) is due to themaximum asymmetric short circuit current.

If the biasing current is small compared to the differential current or the phaseangle between the winding 1 and winding 2 phase currents is close to zero (in anormal situation, the phase difference is 180 degrees), a fault has occurred in thearea protected by TR2PTDF. Then the operation value set for the instantaneousstage is automatically halved and the internal blocking signals of the biased stageare inhibited.



GUID-8B8EC6FC-DF75-4674-808B-7B4C68E9F3E8 V1 EN

Figure 183: Operating characteristics of the protection. (LS) stands for thebiased low stage and (HS) for the instantaneous high stage

The OPERATE output is activated always when the OPR_HS output activates .

The internal blocking signals of the differential function do not prevent the operatesignal of the instantaneous differential current stage. When required, the operateoutputs of the instantaneous high stage can be blocked by the BLK_OPR_HS andBLOCK external control signals.

GUID-9AACAC66-BF72-430C-AAC7-2E52C3DC4487 V1 EN

Figure 184: Operation logic of instantaneous high stage

Reset of the blocking signals (de-block)All three blocking signals, that is, waveform and second and fifth harmonic, have acounter, which holds the blocking on for a certain time after the blockingconditions have ceased to be fulfilled. The deblocking takes place when thosecounters have elapsed. This is a normal case of deblocking.

The blocking signals can be reset immediately if a very high differential current ismeasured or if the phase difference of the compared currents (the angle betweenthe compared currents) is close to zero after the automatic vector group matchinghas been made (in a normal situation, the phase difference is 180 degrees). This



does not, however, reset the counters holding the blockings, so the blocking signalsmay return when these conditions are not valid anymore.

External blocking functionalityTR2PTDF has three inputs for blocking.

• When the BLOCK input is active ("TRUE"), the operation of the function isblocked but measurement output signals are still updated.

• When the BLK_OPR_LS input is active ("TRUE"), TR2PTDF operatesnormally except that the OPR_LS output is not active or activated in anycircumstance. Additionally, the OPERATE output can be activated only by theinstantaneous high stage (if not blocked as well).

• When the BLK_OPR_HS input is active ("TRUE"), TR2PTDF operatesnormally except that the OPR_HS output is not active or activated in anycircumstance. Additionally, the OPERATE output can be activated only by thebiased low stage (if not blocked as well).

4.3.2.5 Application

TR2PTDF is a unit protection function serving as the main protection fortransformers in case of winding failure. The protective zone of a differentialprotection includes the transformer, the bus-work or the cables between the currenttransformer and the power transformer. When bushing current transformers areused for the differential IED, the protective zone does not include the bus work orcables between the circuit breaker and the power transformer.

In some substations, there is a current differential protection for the busbar. Thebusbar protection includes bus work or cables between the circuit breaker and thepower transformer. Internal electrical faults are very serious and cause immediatedamage. Short circuits and earth faults in windings and terminals are normallydetected by the differential protection. If enough turns are short-circuited, theinterturn faults, which are flashovers between the conductors within the samephysical winding, are also detected. The interturn faults are the most difficulttransformer-winding faults to detect with electrical protections. A small interturnfault including a few turns results in an undetectable amount of current until thefault develops into an earth fault. Therefore, it is important that the differentialprotection has a high level of sensitivity and that it is possible to use a sensitivesetting without causing unwanted operations for external faults.

It is important that the faulty transformer is disconnected as fast as possible. AsTR2PTDF is a unit protection function, it can be designed for fast tripping, thusproviding a selective disconnection of the faulty transformer. TR2PTDF shouldnever operate to faults outside the protective zone.

TR2PTDF compares the current flowing into the transformer to the current leavingthe transformer. A correct analysis of fault conditions by TR2PTDF must considerthe changes to voltages, currents and phase angles. The traditional transformerdifferential protection functions required auxiliary transformers for the correction



of the phase shift and turns ratio. The numerical microprocessor based differentialalgorithm implemented in TR2PTDF compensates for both the turns ratio and thephase shift internally in the software.

The differential current should theoretically be zero during normal load or externalfaults if the turns ratio and the phase shift are correctly compensated. However,there are several different phenomena other than internal faults that causeunwanted and false differential currents. The main reasons for unwanteddifferential currents are:

• Mismatch due to varying tap changer positions• Different characteristics, loads and operating conditions of the current

transformers• Zero sequence currents that only flow on one side of the power transformer• Normal magnetizing currents• Magnetizing inrush currents• Overexcitation magnetizing currents.

TR2PTDF is designed mainly for the protection of two-winding transformers.TR2PTDF can also be utilized for the protection of generator-transformer blocks aswell as short cables and overhead lines. If the distance between the measuringpoints is relatively long in line protection, interposing CTs can be required toreduce the burden of the CTs.

GUID-B326703C-3645-4256-96AD-DA87FC9E9C67 V1 EN

Figure 185: Differential protection of a generator-transformer block and shortcable/line

TR2PTDF can also be used in three-winding transformer applications or two-winding transformer applications with two output feeders.



On the double-feeder side of the power transformer, the current of the two CTs perphase must be summed by connecting the two CTs of each phase in parallel.Generally this requires the interposing CTs to handle the vector group and/or ratiomismatch between the two windings/feeders.

The accuracy limit factor for the interposing CT must fulfill the same requirementsas the main CTs. Please note that the interposing CT imposes an additional burdento the main CTs.

The most important rule in these applications is that at least 75 percent of the short-circuit power has to be fed on the side of the power transformer with only oneconnection to the IED.

GUID-799588E3-C63F-4687-98C5-FF48284676DF V1 EN

Figure 186: Differential protection of a three-winding transformer and atransformer with two output feeders

TR2PTDF can also be used for the protection of the power transformer feeding thefrequency converter. An interposing CT is required for matching the three-windingtransformer currents to a two-winding protection relay.

The fundamental frequency component is numerically filtered with a Fourier filter,DFT. The filter suppresses frequencies other than the set fundamental frequency,and therefore the IED is not adapted for measuring the output of the frequencyconverter, that is, TR2PTDF is not suited for protecting of a power transformer ormotor fed by a frequency converter



GUID-46FDF23A-7E78-4B17-A888-8501484AB57A V1 EN

Figure 187: Protection of the power transformer feeding the frequency converter

Transforming ratio correction of CTsThe CT secondary currents often differ from the rated current at the rated load ofthe power transformer. The CT transforming ratios can be corrected on both sidesof the power transformer with the CT ratio Cor Wnd 1 and CT ration Cor Wnd 2settings.

First, the rated load of the power transformer must be calculated on both sideswhen the apparent power and phase-to-phase voltage are known.

IS

UnT

n

n

=

×3

GUID-B5467DB8-17EB-4D09-A741-1F5BB23466AA V1 EN (Equation 39)

InT rated load of the power transformer

Sn rated power of the power transformer

Un rated phase-to-phase voltage

Next, the settings for the CT ratio correction can be calculated.



CT ratio correction =

I

I

n

nT

1

GUID-F5F45645-C809-4F99-B783-751C8CC822BF V1 EN (Equation 40)

I1n nominal primary current of the CT

After the CT ratio correction, the measured currents and corresponding settingvalues of TR2PTDF are expressed in multiples of the rated power transformercurrent Ir (xIr) or percentage value of Ir (%Ir).

ExampleThe rated power of the transformer is 25 MVA, the ratio of the CTs on the 110 kVside is 300/1 and that on the 21 kV side is 1000/1

GUID-DC9083B2-CB07-4F6B-8C06-52979E5F484A V1 EN

Figure 188: Example of two-winding power transformer differential protection

The rated load of the transformer is calculated:

HV side: InT_Wnd1 = 25 MVA / (1.732 x 110 kV) = 131.2 A

LV side: InT_Wnd2 = 25 MVA / (1.732 x 21 kV) = 687.3 A

Settings:CT ratio Cor Wnd 1= 300 A / 131.2 A = “2.29”

CT ratio Cor Wnd 2= 1000 A / 687.3 A = “1.45”

Vector group matching and elimination of the zero-sequencecomponentThe vector group of the power transformer is numerically matched on the highvoltage and low voltage sides by means of the Winding 1 type, Winding 2 type andClock number settings. Thus no interposing CTs are needed if there is only a powertransformer inside the protected zone. The matching is based on phase shifting anda numerical delta connection in the IED. If the neutral of a star-connected powertransformer is earthed, any earth fault in the network is perceived by the IED as a



differential current. The elimination of the zero-sequence component can beselected for that winding by setting the Zro A elimination parameter.

Table 304: TR2PTDF settings corresponding to the power transformer vector groups and zero-sequence elimination

Vector group of thetransformer

Winding 1 type Winding 2 type Clock number Zro A Elimination

Yy0 Y y Clk Num 0 Not needed

YNy0 YN y Clk Num 0 HV side

YNyn0 YN yn Clk Num 0 HV & LV side

Yyn0 Y yn Clk Num 0 LV side


YNy2 YN y Clk Num 2 Not needed

YNyn2 YN yn Clk Num 2 Not needed

Yyn2 Y yn Clk Num 2 Not needed

















Yd1 Y d Clk Num 1 Not needed

YNd1 YN d Clk Num 1 Not needed







Dd0 D d Clk Num 0 Not needed











Dy1 D y Clk Num 1 Not needed

Dyn1 D yn Clk Num 1 Not needed







Yz1 Y z Clk Num 1 Not needed

YNz1 YN z Clk Num 1 Not needed

YNzn1 YN zn Clk Num 1 LV side

Yzn1 Y zn Clk Num 1 Not needed













Zy1 Z y Clk Num 1 Not needed

Zyn1 Z yn Clk Num 1 Not needed

ZNyn1 ZN yn Clk Num 1 HV side

ZNy1 ZN y Clk Num 1 Not needed


















Dz0 D z Clk Num 0 Not needed

Dzn0 D zn Clk Num 0 LV side


Dzn2 D zn Clk Num 2 Not needed




Dzn6 D zn Clk Num 6 LV side





Zd0 Z d Clk Num 0 Not needed

ZNd0 ZN d Clk Num 0 HV side


ZNd2 ZN d Clk Num 2 Not needed




ZNd6 ZN d Clk Num 6 HV side





Zz0 Z z Clk Num 0 Not needed

ZNz0 ZN z Clk Num 0 HV side

ZNzn0 ZN zn Clk Num 0 HV & LV side

Zzn0 Z zn Clk Num 0 LV side


ZNz2 ZN z Clk Num 2 Not needed

ZNzn2 ZN zn Clk Num 2 Not needed

Zzn2 Z zn Clk Num 2 Not needed











ZNz6 ZN z Clk Num 6 HV side

ZNzn6 ZN zn Clk Num 6 HV & LV side

Zzn6 Z zn Clk Num 6 LV side


















































CommissioningThe correct settings, which are CT connection type, Winding 1 type, Winding 2 typeand Clock number, for the connection group compensation can be verified bymonitoring the angle values I_ANGL_A1_B1, I_ANGL_B1_C1,I_ANGL_C1_A1, I_ANGL_A2_B2, I_ANGL_B2_C2, I_ANGL_C2_A2,I_ANGL_A1_A2, I_ANGL_B1_B2 and I_ANGL_C1_C2 while injecting thecurrent into the transformer. These angle values are calculated from thecompensated currents. See signal description from Monitored data table.

When a station service transformer is available, it can be used to provide current tothe high voltage side windings while the low voltage side windings are short-circuited. This way the current can flow in both the high voltage and low voltagewindings. The commissioning signals can be provided by other means as well. Theminimum current to allow for phase current and angle monitoring is 0.015 Ir.

GUID-5ACBF127-85A3-4E5E-A130-9F7206A2DB4C V1 EN

Figure 189: Low voltage test arrangement. The three-phase low voltage sourcecan be the station service transformer.

The Tapped winding control setting parameter has to be set to “Not in use” to makesure that the monitored current values are not scaled by the automatic adaptation tothe tap changer position. When only the angle values are required, the setting ofTapped winding is not needed since angle values are not affected by the tapchanger position adaptation.



When injecting the currents in the high voltage winding, the angle valuesI_ANGL_A1_B1, I_ANGL_B1_C1, I_ANGL_C1_A1, I_ANGL_A2_B2,I_ANGL_B2_C2 and I_ANGL_C2_A2 have to show +120 deg. Otherwise thephase order can be wrong or the polarity of a current transformer differs from thepolarities of the other current transformers on the same side.

If the angle values I_ANGL_A1_B1, I_ANGL_B1_C1 and I_ANGL_C1_A1show -120 deg, the phase order is wrong on the high voltage side. If the anglevalues I_ANGL_A2_B2, I_ANGL_B2_C2 and I_ANGL_C2_A2 show -120 deg,the phase order is wrong on the low voltage side. If the angle valuesI_ANGL_A1_B1, I_ANGL_B1_C1 and I_ANGL_C1_A1 do not show the samevalue of +120, the polarity of one current transformer can be wrong. For instance,if the polarity of the current transformer measuring IL2 is wrong,I_ANGL_A1_B1 shows -60 deg, I_ANGL_B1_C1 shows -60 deg andI_ANGL_C1_A1 shows +120 deg.

When the phase order and the angle values are correct, the angle valuesI_ANGL_A1_A2, I_ANGL_B1_B2 and I_ANGL_C1_C2 usually show ±180deg. There can be several reasons if the angle values are not ±180 deg. If the valuesare 0 deg, the value given for CT connection type is probably wrong. If the anglevalues are something else, the value for Clock number can be wrong. Anotherreason is that the combination of Winding 1 type and Winding 2 type does notmatch Clock number. This means that the resulting connection group is not supported.

ExampleIf Winding 1 type is set to "Y", Winding 2 type is set to "y" and Clock number is setto "Clk num 1", the resulting connection group "Yy1" is not a supportedcombination. Similarly if Winding 1 type is set to "Y", Winding 2 type is set to "d"and Clock number is set to "Clk num 0", the resulting connection group "Yd0" isnot a supported combination. All the non-supported combinations of Winding 1type, Winding 2 type and Clock number settings result in the default connectiongroup compensation that is "Yy0".

Recommendations for current transformersThe more important the object to be protected, the more attention has to be paid tothe current transformers. It is not normally possible to dimension the currenttransformer so that they repeat the currents with high DC components withoutsaturating when the residual flux of the current transformer is high. TR2PTDFoperates reliably even though the current transformers are partially saturated.

The accuracy class recommended for current transformers to be used withTR2PTDF is 5P, in which the limit of the current error at the rated primary currentis 1 percent and the limit of the phase displacement is 60 minutes. The limit of thecomposite error at the rated accuracy limit primary current is 5 percent.

The approximate value of the accuracy limit factor Fa corresponding to the actualcurrent transformer burden can be calculated on the basis of the rated accuracy



limit factor Fn at the rated burden, the rated burden Sn, the internal burden Sinandthe actual burden Sa of the current transformer.

F FS S

S Sa n

in n

in a

= ×+

+

GUID-26DEE538-9E1A-49A2-9C97-F69BD44591C9 V2 EN (Equation 41)

Fa The approximate value of the accuracy limit factor (ALF) corresponding to the actual CT burden

Fn The rated accuracy limit factor at the rated burden of the current transformer

Sn The rated burden of the current transformer

Sin The internal burden of the current transformer

Sa The actual burden of the current transformer

Example 1The rated burden Sn of the current transformer 5P20 is 10 VA, the secondary ratedcurrent is 5A, the internal resistance Rin= 0.07 Ω and the accuracy limit factor Fncorresponding to the rated burden is 20 (5P20). Thus the internal burden of thecurrent transformer is Sin= (5A)2 * 0.07 Ω = 1.75 VA. The input impedance of theIED at a rated current of 5A is < 20 mΩ. If the measurement conductors have aresistance of 0.113 Ω, the actual burden of the current transformer is Sa=(5A)2 *(0.113 + 0.020) Ω = 3.33 VA. Thus the accuracy limit factor Fa corresponding tothe actual burden is approximately 46.

The CT burden can grow considerably at the rated current 5A. The actual burden ofthe current transformer decreases at the rated current of 1A while the repeatabilitysimultaneously improves.

At faults occurring in the protected area, the currents may be very high comparedto the rated currents of the current transformers. Due to the instantaneous stage ofthe differential function block, it is sufficient that the current transformers arecapable of repeating the current required for instantaneous tripping during the firstcycle.

Thus the current transformers usually are able to reproduce the asymmetric faultcurrent without saturating within the next 10 ms after the occurrence of the fault tosecure that the operate times of the IED comply with the retardation time.

The accuracy limit factors corresponding to the actual burden of the phase currenttransformer to be used in differential protection fulfill the requirement.

F K Ik T ea r dc

T Tm dc> × × × × − +−

max/

( ( ) )ω 1 1

GUID-DA861DAD-C40E-4A82-8973-BBAFD15279C0 V1 EN (Equation 42)

Ikmax The maximum through-going fault current (in Ir) at which the protection is not allowed to operate

Tdc The primary DC time constant related to Ikmax



ω The angular frequency, that is, 2*π*fn

Tm The time-to-saturate, that is, the duration of the saturation free transformation

Kr The remanence factor 1/(1-r), where r is the maximum remanence flux in p.u. from saturation flux

The accuracy limit factors corresponding to the actual burden of the phase currenttransformer is used in differential protection.

The parameter r is the maximum remanence flux density in the CT core in p.u.from saturation flux density. The value of the parameter r depends on the magneticmaterial used and on the construction of the CT. For instance, if the value of r =0.4, the remanence flux density can be 40 percent of the saturation flux density.The manufacturer of the CT has to be contacted when an accurate value for theparameter r is needed. The value r = 0.4 is recommended to be used when anaccurate value is not available.

The required minimum time-to-saturate Tm in TR2PTDF is half fundamental cycleperiod (10 ms when fn = 50Hz).

Two typical cases are considered for the determination of the sufficient accuracylimit factor (Fa):

1. A fault occurring at the substation bus:The protection must be stable at a fault arising during a normal operatingsituation. Re-energizing the transformer against a bus fault leads to very highfault currents and thermal stress and therefore re-energizing is not preferred inthis case. Thus, the remanence can be neglected.The maximum through-going fault current Ikmax is typically 10 Ir for asubstation main transformer. At a short circuit fault close to the supplytransformer, the DC time constant (Tdc) of the fault current is almost the sameas that of the transformer, the typical value being 100 ms.

Ikmax 10 Ir

Tdc 100 ms

ω 100π Hz

Tm 10 ms

Kr 1

When the values are substituted in Equation 42, the result is:

Fa > × × × × − + ≈−

K Ik T er dc

T Tm dcmax

/( ( ) )ω 1 1 40

GUID-7F1019C5-C819-440B-871B-5CFD1AF88956 V1 EN

2. Re-energizing against a fault occurring further down in the network:



The protection must be stable also during re-energization against a fault on theline. In this case, the existence of remanence is very probable. It is assumed tobe 40 percent here.On the other hand, the fault current is now smaller and since the ratio of theresistance and reactance is greater in this location, having a full DC offset isnot possible. Furthermore, the DC time constant (Tdc) of the fault current isnow smaller, assumed to be 50 ms here.Assuming a maximum fault current being 30 percent lower than in the busfault and a DC offset 90 percent of the maximum.

Ikmax 0.7* 10 = 7 (Ir)

Tdc 50 ms

ω 100π Hz

Tm 10 ms

Kr 1/(1-0.4) = 1.6667

When the values are substituted in the equation, the result is:

Fa > × × × × × − + ≈−

K Ik T er dc

T Tm dcmax

/. ( ( ) )0 9 1 1 40ω

GUID-9B859B2D-AC40-4278-8A99-3475442D7C67 V1 EN

If the actual burden of the current transformer (Sa) in Equation 41 cannot bereduced low enough to provide a sufficient value for Fa, there are twoalternatives to deal with the situation:• a CT with a higher rated burden Sn can be chosen (which also means a

higher rated accuracy limit Fn)• a CT with a higher nominal primary current I1n (but the same rated

burden) can be chosen

Example 2Assuming that the actions according to alternative two above are taken in order toimprove the actual accuracy limit factor:

FIrCT

IrTRFa n= *

GUID-31A3C436-4E17-40AE-A4EA-D2BD6B72034E V1 EN (Equation 43)

IrTR 1000 A (rated secondary side current of the power transformer)

IrCT 1500 A (rated primary current of the CT on the transformer secondary side)

Fn 30 (rated accuracy limit factor of the CT)

Fa (IrCT / IrTR) * Fn (actual accuracy limit factor due to oversizing the CT) = (1500/1000) * 30 = 45



In TR2PTDF, it is important that the accuracy limit factors Fa of the phase currenttransformers at both sides correspond with each other, that is, the burdens of thecurrent transformers on both sides are to be as equal as possible. If high inrush orstart currents with high DC components pass through the protected object when itis connected to the network, special attention is required for the performance andthe burdens of the current transformers and for the settings of the function block.

4.3.2.6 CT connections and transformation ratio correction

The connections of the primary current transformers are designated as "Type 1"and "Type 2".

• If the positive directions of the winding 1 and winding 2 IED currents areopposite, the CT connection type setting parameter is "Type 1". Theconnection examples of "Type 1" are as shown in Figure 190 and Figure 191.

• If the positive directions of the winding 1 and winding 2 IED currents equate,the CT connection type setting parameter is "Type 2". The connectionexamples of "Type 2" are as shown in Figure 192 and Figure 193.

• The default value of the CT connection type setting is "Type 1".



L1 L2 L3

789

101112

X120

1/5AN

1/5AN

1/5AN

IL1

IL2

IL3

123456

1/5AN

1/5AN

1/5AN

IL1B

IL2B

IL3B

X120

P1

P2

P1

P2

S1

S2

S1S2

GUID-53F7DCB6-58B8-418C-AB83-805B4B0DCCAE V2 EN

Figure 190: Connection example of current transformers of Type 1



L1 L2 L3

789101112

123456

1/5AN

1/5AN

1/5AN

IL1B

IL2B

IL3B

X120

X120

1/5AN

1/5AN

1/5AN

IL1

IL2

IL3

P2

P1

P2

P1

S1

S1

S2

S2

GUID-24C391DC-D767-4848-AE98-FE33C1548DEE V1 EN

Figure 191: Alternative connection example of current transformers of Type 1



L1 L2 L3

789101112

123456

1/5AN

1/5AN

1/5AN

IL1B

IL2B

IL3B

X120

X120

1/5AN

1/5AN

1/5AN

IL1

IL2

IL3

P1

P2

P1

P2

S1

S2

S1

S2

GUID-66D375DD-BF49-43C5-A7B5-BFA2BEAD035C V2 EN

Figure 192: Connection of current transformers of Type 2 and example of thecurrents during an external fault



L1 L2 L3

789101112

123456

1/5AN

1/5AN

1/5AN

IL1B

IL2B

IL3B

X120

X120

1/5AN

1/5AN

1/5AN

IL1

IL2

IL3

P1

P2

P1

P2

S1S2

S1S2

GUID-5E0D15BA-ADA9-4FE0-A85D-5C6E86D7E32B V1 EN

Figure 193: Alternative connection example of current transformers of Type 2

The CT secondary currents often differ from the rated current at the rated load ofthe power transformer. The CT transforming ratios can be corrected on both sidesof the power transformer with the CT ratio Cor Wnd 1 and CT ratio Cor Wnd 2settings.

4.3.2.7 Signals

Table 305: TR2PTDF Input signals

Name Type Default DescriptionI_A1 SIGNAL 0 Phase A primary current

I_B1 SIGNAL 0 Phase B primary current

I_C1 SIGNAL 0 Phase C primary current

I_A2 SIGNAL 0 Phase A secondary current

I_B2 SIGNAL 0 Phase B secondary current




Name Type Default DescriptionI_C2 SIGNAL 0 Phase C secondary current

BLOCK BOOLEAN 0=False Block

BLK_OPR_LS BOOLEAN 0=False Blocks operate outputs from biased stage

BLK_OPR_HS BOOLEAN 0=False Blocks operate outputs from instantaneous stage

Table 306: TR2PTDF Output signals

Name Type DescriptionOPERATE BOOLEAN Operate combined

OPR_LS BOOLEAN Operate from low set

OPR_HS BOOLEAN Operate from high set

BLKD2H BOOLEAN 2nd harmonic restraint block status

BLKD5H BOOLEAN 5th harmonic restraint block status

BLKDWAV BOOLEAN Waveform blocking status

4.3.2.8 Settings

Table 307: TR2PTDF Group settings

Parameter Values (Range) Unit Step Default DescriptionHigh operate value 500...3000 %Ir 10 1000 Instantaneous stage setting

Enable high set 0=False1=True

1=True Enable high set stage

Low operate value 5...50 %Ir 1 20 Basic setting for biased operation

Slope section 2 10...50 % 1 30 Slope of the second line of the operatingcharacteristics

End section 2 100...500 %Ir 1 150 Turn-point between the second and thethird line of the operating characteristics

Restraint mode -1=2.h + 5.h + wav5=Waveform6=2.h + waveform7=5.h + waveform

-1=2.h + 5.h + wav Restraint mode

Harmonic deblock 2. 0=False1=True

1=True 2. harmonic deblocking in case of switchon to fault

Start value 2.H 7...20 % 1 15 2. harmonic blocking ratio

Start value 5.H 10...50 % 1 35 5. harmonic blocking ratio

Stop value 5.H 10...50 % 1 35 5. harmonic deblocking ratio

Harmonic deblock 5. 0=False1=True

0=False 5. harmonic deblocking in case of severeovervoltage



Table 308: TR2PTDF Non group settings


5=off 1=on Operation Off/On


1=Type 1 CT connection type. Determined by thedirections of the connected currenttransformers

Winding 1 type 1=Y2=YN3=D4=Z5=ZN

1=Y Connection of the HV side windings

Winding 2 type 1=y2=yn3=d4=z5=zn

1=y Connection of the LV side windings

Clock number 0=Clk Num 01=Clk Num 12=Clk Num 24=Clk Num 45=Clk Num 56=Clk Num 67=Clk Num 78=Clk Num 810=Clk Num 1011=Clk Num 11

0=Clk Num 0 Setting the phase shift between HV andLV with clock number for connectiongroup compensation (e.g. Dyn11 -> 11)

Zro A elimination 1=Not eliminated2=Winding 13=Winding 24=Winding 1 and 2

1=Not eliminated Elimination of the zero-sequence current

Min winding tap -36...36 1 36 The tap position number resulting theminimum number of effective windingturns on the side of the transformerwhere the tap changer is.

Max winding tap -36...36 1 0 The tap position number resulting themaximum number of effective windingturns on the side of the transformerwhere the tap changer is.

Tap nominal -36...36 1 18 The nominal position of the tap changerresulting the default transformation ratioof the transformer (as if there was no tapchanger)

Tapped winding 1=Not in use2=Winding 13=Winding 2

1=Not in use The winding where the tap changer isconnected to

Step of tap 0.60...9.00 % 0.01 1.50 The percentage change in voltagecorresponding one step of the tap changer

CT ratio Cor Wnd 1 0.40...4.00 0.01 1.00 CT ratio correction, winding 1

CT ratio Cor Wnd 2 0.40...4.00 0.01 1.00 CT ratio correction, winding 2




Table 309: TR2PTDF Monitored data

Name Type Values (Range) Unit DescriptionOPR_A BOOLEAN 0=False

1=True Operate phase A

OPR_B BOOLEAN 0=False1=True

Operate phase B

OPR_C BOOLEAN 0=False1=True

Operate phase C

BLKD2H_A BOOLEAN 0=False1=True

2nd harmonic restraintblock phase A status

BLKD2H_B BOOLEAN 0=False1=True

2nd harmonic restraintblock phase B status

BLKD2H_C BOOLEAN 0=False1=True

2nd harmonic restraintblock phase C status

BLKD5H_A BOOLEAN 0=False1=True

5th harmonic restraintblock phase A status

BLKD5H_B BOOLEAN 0=False1=True

5th harmonic restraintblock phase B status

BLKD5H_C BOOLEAN 0=False1=True

5th harmonic restraintblock phase C status

BLKDWAV_A BOOLEAN 0=False1=True

Waveform blockingphase A status

BLKDWAV_B BOOLEAN 0=False1=True

Waveform blockingphase B status

BLKDWAV_C BOOLEAN 0=False1=True

Waveform blockingphase C status

BLKD2HPHAR BOOLEAN 0=False1=True

2nd harmonic restraintblocking for PHAR LN,combined

BLKD2HPHAR_A BOOLEAN 0=False1=True

2nd harmonic restraintblocking for PHAR LN,phase A

BLKD2HPHAR_B BOOLEAN 0=False1=True

2nd harmonic restraintblocking for PHAR LN,phase B

BLKD2HPHAR_C BOOLEAN 0=False1=True

2nd harmonic restraintblocking for PHAR LN,phase C

BLKD5HPHAR BOOLEAN 0=False1=True

5th harmonic restraintblocking for PHAR LN,combined

BLKD5HPHAR_A BOOLEAN 0=False1=True

5th harmonic restraintblocking for PHAR LN,phase A

BLKD5HPHAR_B BOOLEAN 0=False1=True

5th harmonic restraintblocking for PHAR LN,phase B

BLKD5HPHAR_C BOOLEAN 0=False1=True

5th harmonic restraintblocking for PHAR LN,phase C




Name Type Values (Range) Unit DescriptionI_AMPL_A1 FLOAT32 0.00...40.00 xIr Connection group

compensated primarycurrent phase A

I_AMPL_B1 FLOAT32 0.00...40.00 xIr Connection groupcompensated primarycurrent phase B

I_AMPL_C1 FLOAT32 0.00...40.00 xIr Connection groupcompensated primarycurrent phase C

I_AMPL_A2 FLOAT32 0.00...40.00 xIr Connection groupcompensated secondarycurrent phase A

I_AMPL_B2 FLOAT32 0.00...40.00 xIr Connection groupcompensated secondarycurrent phase B

I_AMPL_C2 FLOAT32 0.00...40.00 xIr Connection groupcompensated secondarycurrent phase C

ID_A FLOAT32 0.00...80.00 xIr Differential Currentphase A

ID_B FLOAT32 0.00...80.00 xIr Differential Currentphase B

ID_C FLOAT32 0.00...80.00 xIr Differential Currentphase C

IB_A FLOAT32 0.00...80.00 xIr Biasing current phase A

IB_B FLOAT32 0.00...80.00 xIr Biasing current phase B

IB_C FLOAT32 0.00...80.00 xIr Biasing current phase C

I_2H_RAT_A FLOAT32 0.00...1.00 Differential currentsecond harmonic ratio,phase A

I_2H_RAT_B FLOAT32 0.00...1.00 Differential currentsecond harmonic ratio,phase B

I_2H_RAT_C FLOAT32 0.00...1.00 Differential currentsecond harmonic ratio,phase C

I_ANGL_A1_B1 FLOAT32 -180.00...180.00 deg Current phase anglephase A to B, winding 1

I_ANGL_B1_C1 FLOAT32 -180.00...180.00 deg Current phase anglephase B to C, winding 1

I_ANGL_C1_A1 FLOAT32 -180.00...180.00 deg Current phase anglephase C to A, winding 1

I_ANGL_A2_B2 FLOAT32 -180.00...180.00 deg Current phase anglephase A to B, winding 2

I_ANGL_B2_C2 FLOAT32 -180.00...180.00 deg Current phase anglephase B to C, winding 2

I_ANGL_C2_A2 FLOAT32 -180.00...180.00 deg Current phase anglephase C to A, winding 2

I_ANGL_A1_A2 FLOAT32 -180.00...180.00 deg Current phase angle diffbetween winding 1 and2, phase A




Name Type Values (Range) Unit DescriptionI_ANGL_B1_B2 FLOAT32 -180.00...180.00 deg Current phase angle diff

between winding 1 and2, phase B

I_ANGL_C1_C2 FLOAT32 -180.00...180.00 deg Current phase angle diffbetween winding 1 and2, phase C

I_5H_RAT_A FLOAT32 0.00...1.00 Differential current fifthharmonic ratio, phase A

I_5H_RAT_B FLOAT32 0.00...1.00 Differential current fifthharmonic ratio, phase B

I_5H_RAT_C FLOAT32 0.00...1.00 Differential current fifthharmonic ratio, phase C

TR2PTDF Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 310: TR2PTDF Technical data


measured: fn ±2 Hz


Operate time1)2) Minimum Typical Maximum

Low stageHigh stage

34 ms21 ms

40 ms22 ms

44 ms24 ms

Reset time < 40 ms


Suppression of harmonics DFT: -50 dB at f = n x fn, where n = 2, 3, 4, 5, …

1) Current before fault = 0.0, fn = 50 Hz, results based on statistical distribution of 1000 measurements2) Includes the delay of the output contact. When differential current = 2 x set operate value and fn =

50 Hz.

4.3.3 Numerically stabilized low-impedance restricted earth-faultprotection LREFPNDF





Numerically stabilized low-impedancerestricted earth-fault protection

LREFPNDF dIoLo> 87NL




GUID-A04FED1B-8424-4A84-A327-262E4CC5628F V2 EN



The stabilized restricted low-impedance earth-fault protection LREFPNDF for a two-winding transformer is based on the numerically stabilized differential currentprinciple. No external stabilizing resistor or non-linear resistor are required.

The fundamental components of the currents are used for calculating the residualcurrent of the phase currents, the neutral current, differential currents andstabilizing currents. The operating characteristics are according to the definite time.

LREFPNDF contains a blocking functionality. The neutral current secondharmonic is used for blocking during the transformer inrush situation. It is alsopossible to block function outputs, timers or the function itself, if desired.



The operation of the stabilized restricted low-impedance earth-fault protection canbe described using a module diagram. All the modules in the diagram are explainedin the next sections.

GUID-079EB39A-B62C-47DF-9B53-9432AB24A9CE V2 EN




Earth-fault detectorThe operation is based on comparing the amplitude and the phase differencebetween the sum of the fundamental frequency component of the phase currents(ΣI, residual current) and the fundamental frequency component of the neutralcurrent (Io) flowing in the conductor between the transformer or generator's neutralpoint and earth. The differential current is calculated as the absolute value of thedifference between the residual current, that is, the sum of the fundamentalfrequency components of the phase currents I_A, I_B and I_C, and the neutralcurrent. The directional differential current ID_COSPHI is the product of thedifferential current and cosφ. The value is available in the monitored data view.

ID COSPHI I Io_ ( ) cos= − ×Σ ϕ

GUID-46782962-D465-47D2-8ECE-3FF0B87B324F V3 EN (Equation 44)

ΣIGUID-87E4DEDD-9288-41D9-B608-714CF3CC7A04 V1 EN

Residual current

ϕ

GUID-C4F98C50-7279-4DAA-8C77-5C761572F4B4 V1 EN

Phase difference between the residual and neutral currents

Io

GUID-2D713C98-4F81-4DF4-8193-C47120A65489 V1 EN

Neutral current

An earth fault occurring in the protected area, that is, between the phase CTs andthe neutral connection CT, causes a differential current. The directions, that is, thephase difference of the residual current and the neutral current, are considered inthe operation criteria to maintain selectivity. A correct value for CT connectiontype is determined by the connection polarities of the current transformer.

The current transformer ratio mismatch between the phase currenttransformer and neutral current transformer (residual current in theanalog input settings) is taken into account by the function with theproperly set analog input setting values.

During an earth fault in the protected area, the currents ΣI and Io are directedtowards the protected area. The factor cosφ is 1 when the phase difference of theresidual current and the neutral current is 180 degrees, that is, when the currents arein opposite direction at the earth faults within the protected area. Similarly,ID_COSPHI is specified to be 0 when the phase difference between the residualcurrent and the neutral current is less than 90 degrees in situations where there isno earth fault in the protected area. Thus tripping is possible only when the phasedifference between the residual current and the neutral current is above 90 degrees.

The stabilizing current IB used by the stabilizing current principle is calculated asan average of the phase currents in the windings to be protected. The value isavailable in the monitored data view.



IB

I A I B I C

=

+ +_ _ _

3

GUID-E162EE11-DEDF-49BA-B60F-E22ECF1ACAE8 V2 EN (Equation 45)

GUID-9D592151-7598-479B-9285-7FB7C09F0FAB V1 EN

Figure 196: Operating characteristics of the stabilized earth-fault protectionfunction

GUID-552423CA-6FE9-4F69-8341-FFE0FF1943D4 V1 EN

Figure 197: Setting range of the operating characteristics for the stabilizeddifferential current principle of the earth-fault protection function

The Operate value setting is used for defining the characteristics of the function.The differential current value required for tripping is constant at the stabilizingcurrent values 0.0 < IB/In < 1.0, where In is the nominal current, and the In in thiscontext refers to the nominal of the phase current inputs. When the stabilizingcurrent is higher than 1.0, the slope of the operation characteristic (ID/IB) isconstant at 50 percent. Different operating characteristics are possible based on theOperate value setting.



To calculate the directional differential current ID_COSPHI, the fundamentalfrequency amplitude of both the residual and neutral currents has to be above 4percent of In. If neither or only one condition is fulfilled at a time, the cosφ term isforced to 1. After the conditions are fulfilled, both currents must stay above 2percent of In to allow the continuous calculation of the cosφ term.

Second harmonic blockingThis module compares the ratio of the current second harmonic (I0_2H) and I0 tothe set value Start value 2.H. If the ratio (I0_2H / I0) value exceeds the set value,the BLK2H output is activated.

The blocking also prevents unwanted operation at the recovery and sympatheticmagnetizing inrushes. At the recovery inrush, the magnetizing current of thetransformer to be protected increases momentarily when the voltage returns tonormal after the clearance of a fault outside the protected area. The sympatheticinrush is caused by the energization of a transformer running in parallel with theprotected transformer connected to the network.

The second harmonic blocking is disabled when Restraint mode is set to "None"and enabled when set to "Harmonic2".

TimerOnce activated, the timer activates the START output. The time characteristic isaccording to DT. When the operation timer has reached the value set by Minimumoperate time, the OPERATE output is activated. If the fault disappears before themodule operates, the reset timer is activated. If the reset timer reaches the value setby Reset delay time, the reset timer resets and the START output is deactivated.

The timer calculates the start duration value START_DUR which indicates thepercentage ratio of the start situation and the set operate time. The value isavailable through the Monitored data view.


The Blocking mode setting has three blocking methods. In the "Freeze timers"mode, the operate timer is frozen to the prevailing value. In the "Block all" mode,the whole function is blocked and the timers are reset. In the "Block OPERATEoutput" mode, the function operates normally but the OPERATE output is notactivated.

The activation of the output of the second harmonic blocking signal BLK2Hdeactivates the OPERATE output.



4.3.3.5 Application

An earth-fault protection using an overcurrent element does not adequately protectthe transformer winding in general and the star-connected winding in particular.

The restricted earth-fault protection is mainly used as a unit protection for thetransformer windings. LREFPNDF is a sensitive protection applied to protect the star-connected winding of a transformer. This protection system remains stable for allthe faults outside the protected zone.

LREFPNDF provides higher sensitivity for the detection of earth faults than theoverall transformer differential protection. This is a high-speed unit protectionscheme applied to the star-connected winding of the transformer. LREFPNDF isnormally applied when the transformer is earthed solidly or through low-impedance resistor (NER). LREFPNDF can be also applied on the delta side of thetransformer if an earthing transformer (zig-zag transformer) is used there. InLREFPNDF, the difference of the fundamental component of all three phasecurrents and the neutral current is provided to the differential element to detect theearth fault in the transformer winding based on the numerical stabilized differentialcurrent principle.

Connection of current transformersThe connections of the main CTs are designated as "Type 1" and "Type 2". In casethe earthings of the current transformers on the phase side and the neutral side areboth either inside or outside the area to be protected, the setting parameter CTconnection type is "Type 1".

If the earthing of the current transformers on the phase side is inside the area to beprotected and the neutral side is outside the area to be protected or if the earthingon the phase side is outside the area and on the neutral side inside the area, thesetting parameter CT connection type is "Type 2".

GUID-63BD73B4-7B60-4354-9690-E96C0A8076C7 V1 EN

Figure 198: Connection of the current transformers of Type 1. The connectedphase currents and the neutral current have opposite directions atan external earth-fault situation.



GUID-124047A0-9B33-4D2F-9519-75D98C0A4534 V1 EN

Figure 199: Connection of the current transformers of Type 2. The phasecurrents and the neutral current have equal directions at anexternal earth-fault situation.

Internal and external faultsLREFPNDF does not respond to any faults outside the protected zone. An externalfault is detected by checking the phase angle difference of the neutral current andthe sum of the phase currents. When the difference is less than 90 degrees, theoperation is internally restrained or blocked. Hence the protection is not sensitiveto an external fault.

A

B

I a = 0

Ib = 0Ib = 0

I c = 0I

Io

zone of protection

C

a

b

c

IN

Izs1

Izs1

Izs1

Io

IN Reference is Neutral Current

Restrain for external fault

Operate for internal fault

For external fault

Uzs

GUID-FAC5E4AD-A4A7-4D39-9EAC-C380EA33CB78 V2 EN

Figure 200: Current flow in all the CTs for an external fault



A

B

C

a

b

c

Ia = 0I

Ib = 0I

c = 0I

UzsIo

zone of protection

Ifault

IN

Io

IN Reference is Neutral Current

Restrain for external fault

Operate for internal fault

For internal fault

source

GUID-D5D712D4-2291-4C49-93DE-363F9F10801C V2 EN

Figure 201: Current flow in all the CTs for an internal fault

LREFPNDF does not respond to phase-to-phase faults either, as in this case thefault current flows between the two line CTs and so the neutral CT does notexperience this fault current.

Blocking based on the second harmonic of the neutral currentThe transformer magnetizing inrush currents occur when the transformer isenergized after a period of de-energization. The inrush current can be many timesthe rated current, and the halving time can be up to several seconds. For thedifferential IED, the inrush current represents the differential current, which causesthe IED to operate almost always when the transformer is connected to thenetwork. Typically, the inrush current contains a large amount of second harmonics.

The blocking also prevents unwanted operation at the recovery and sympatheticmagnetizing inrushes. At the recovery inrush, the magnetizing current of thetransformer to be protected increases momentarily when the voltage returns tonormal after the clearance of a fault outside the protected area. The sympatheticinrush is caused by the energization of a transformer running in parallel with theprotected transformer already connected to the network.

Blocking the starting of the restricted earth-fault protection at the magnetizinginrush is based on the ratio of the second harmonic and the fundamental frequencyamplitudes of the neutral current Io_2H / Io. Typically, the second harmoniccontent of the neutral current at the magnetizing inrush is higher than that of thephase currents.



4.3.3.6 Signals

Table 311: LREFPNDF Input signals




Io SIGNAL 0 Residual current


Table 312: LREFPNDF Output signals


START BOOLEAN Start

BLK2H BOOLEAN 2nd harmonic block

4.3.3.7 Settings

Table 313: LREFPNDF Group settings

Parameter Values (Range) Unit Step Default DescriptionOperate value 5...50 %In 1 5 Operate value

Minimum operate time 40...300000 ms 1 40 Minimum operate time

Restraint mode 1=None2=Harmonic2

1=None Restraint mode

Start value 2.H 10...50 %In 1 50 The ratio of the 2. harmonic tofundamental component required forblocking

Table 314: LREFPNDF Non group settings





2=Type 2 CT connection type




Table 315: LREFPNDF Monitored data


operate time

RES2H BOOLEAN 0=False1=True

2nd harmonic restraint

ID_COSPHI FLOAT32 0.00...80.00 xIn Directional differentialcurrent Id cosphi

IB FLOAT32 0.00...80.00 xIn Bias current

LREFPNDF Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 316: LREFPNDF Technical data


measured: fn ±2 Hz



IFault = 2.0 x setOperate value

38 ms 40 ms 43 ms

Reset time < 40 ms




Suppression of harmonics DFT: -50 dB at f = n x fn, where n = 2, 3, 4, 5, …

1) Current before fault = 0.0, fn = 50 Hz, results based on statistical distribution of 1000 measurements2) Includes the delay of the signal output contact

4.3.4 High-impedance-based restricted earth-fault protectionHREFPDIF


Functional description IEC 61850identification



High-impedance-based restricted earth-fault protection

HREFPDIF dIoHi> 87NH




GUID-0B400966-B2D9-4027-A2B3-786BA559A4A4 V3 EN



The high-impedance-based restricted earth-fault protection HREFPDIF is used forthe restricted earth-fault protection of generators and power transformers.

HREFPDIF starts when the IDo, the differential neutral current, exceeds the setlimit. HREFPDIF operates with the DT characteristic.

HREFPDIF contains a blocking functionality. It is possible to block functionoutputs, timers or the function itself, if desired.



The operation of the high-impedance-based restricted earth-fault protectionfunction can be described using a module diagram. All the modules in the diagramare explained in the next sections.

GUID-75842EE4-C4B8-452A-8FA9-FDE60ED22DD4 V3 EN


Level detectorThe level detector compares the differential neutral current IDo to the set value ofthe Operate value setting. If the differential neutral current exceeds the Operatevalue setting, the level detector sends an enable signal to the timer module to startthe definite timer.

TimerOnce activated, the timer activates the START output. The time characteristic isaccording to DT. When the operation timer has reached the value set by Minimum



operate time, the OPERATE output is activated. If the fault disappears before themodule operates, the reset timer is activated. If the reset timer reaches the value setby Reset delay time, the operation timer resets and the START output is deactivated.

The timer calculates the start duration value START_DUR, which indicates theratio of the start situation and the set operation time. The value is available in themonitored data view.



4.3.4.5 Application

In solidly earthed systems, the restricted earth-fault protection is always deployedas a complement to the normal transformer differential protection. The advantageof the restricted earth-fault protection is its high sensitivity. Sensitivities of close to1.0 percent can be achieved, whereas normal differential IEDs have their minimumsensitivity in the range of 5 to 10 percent. The level for HREFPDIF is dependent ofthe current transformers' magnetizing currents. The restricted earth-fault protectionis also very fast due to the simple measuring principle as it is a unit type of protection.

The differences in measuring principle limit the biased differential IED'spossibility to detect the earth faults. Such faults are then only detected by therestricted earth-fault function.

The restricted earth-fault IED is connected across each directly or to low-ohmicearthed transformer winding. If the same CTs are connected to other IEDs, separatecores are to be used.



s1s2

s1

s2

VDR

StabilizingResistor

High impedance protection

(HREFPDIF)GUID-367BDBC9-D2E8-48D3-B98F-623F7CD70D99 V3 EN

Figure 204: Connection scheme for the restricted earth-fault protectionaccording to the high-impedance principle

High-impedance principleHigh-impedance principle is stable for all types of faults outside the zone ofprotection. The stabilization is obtained by a stabilizing resistor in the differentialcircuit. This method requires that all the CTs used have a similar magnetizingcharacteristic, same ratio and relatively high knee point voltage. CTs on each sidesare connected in parallel along with a relay-measuring branch as shown in Figure205. The measuring branch is a series connection of stabilizing resistor and IED.



Id

CT1

Rm1/2 Rm2/2

RuRs

Rm1/2 Rm2/2

Rin1 Rin2

CT2

GUID-80DC5CFE-118C-4C5C-A15F-13DCB1708C0E V1 EN

Figure 205: High-impedance principle

The stability of the protection is based on the use of the stabilizing resistor (Rs) andthe fact that the impedance of the CT secondary quickly decreases as the CTsaturates. The magnetization reactance of a fully saturated CT goes to zero and theimpedance is formed only by the resistance of the winding (Rin) and lead resistance(Rm).

The CT saturation causes a differential current which now has two paths to flow:through the saturated CT because of the near-zero magnetizing reactance andthrough the measuring branch. The stabilizing resistor is selected as such that thecurrent in the measuring branch is below the relay operating current during out-of-zone faults. As a result, the operation is stable during the saturation and can still besensitive at the non-saturated parts of the current waveform as shown in Figure 206.

In case of an internal fault, the fault current cannot circulate through the CTs but itflows through the measuring branch and the protection operates. Partial CTsaturation can occur in case of an internal fault, but the non-saturated part of thecurrent waveform causes the protection to operate.

Saturated part Non-saturated part

I

GUID-B4CBEF48-1C9C-410B-997F-440CB10486BD V1 EN

Figure 206: Secondary waveform of a saturated CT



At internal fault, the secondary circuit voltage can easily exceed the isolationvoltage of the CTs, connection wires and IED. To limit this voltage, a voltage-dependent resistor VDR is used as shown in Figure 205.

The whole scheme, that is, the stabilizing resistor, voltage-dependent resistor andwiring, must be adequately maintained (operation- and insulation-tested regularly)to be able to withstand the high-voltage pulses which appear during an internalfault throughout the lifetime of the equipment. Otherwise, during a fault within thezone of protection, any flashover in the CT secondary circuits or in any other partof the scheme may prevent a correct operation of the high-impedance differentialfunction.

4.3.4.6 The measuring configuration

The external measuring configuration is composed of four current transformersmeasuring the currents and a stabilizing resistor. A varistor is needed if highovervoltages are expected.

The value of the stabilizing resistor is calculated with the formula:

RU

Is

s

rs

=

GUID-00FCABE9-93E2-4BDD-83C6-EB1BE7FFE986 V1 EN (Equation 46)

Rs the resistance of the stabilizing resistor

Us the stabilizing voltage of the IED

Irs the value of the Low operate value setting

The stabilizing voltage is calculated with the formula:

UI

nR Rs

kin m= +

max( )

GUID-6A4C58E7-3D26-40C9-A070-0D99BA209B1A V1 EN (Equation 47)

Ikmax the highest through-fault current

n the turns ratio of the CT

Rin the secondary internal resistance of the CT

Rm the resistance of the longest loop of secondary circuit

Additionally, it is required that the current transformers' knee-point voltages Uk areat least twice the stabilizing voltage value Us.



4.3.4.7 Recommendations for current transformers

The sensitivity and reliability of the protection depends a lot on the characteristicsof the current transformers. The CTs must have an identical transformation ratio. Itis recommended that all current transformers have an equal burden andcharacteristics and are of same type, preferably from the same manufacturingbatch, that is, an identical construction should be used. If the CT characteristics andburden values are not equal, calculation for each branch in the scheme should bedone separately and the worst-case result is then used.

First, the stabilizing voltage, that is, the voltage appearing across the measuringbranch during the out-of-zone fault, is calculated assuming that one of the parallelconnected CT is fully saturated. The stabilizing voltage can be calculated with theformula

UI

nR Rs

kin m= +

max( )

GUID-6A4C58E7-3D26-40C9-A070-0D99BA209B1A V1 EN (Equation 48)

Ikmax the highest through-fault current in primary amps. The highest earth-fault or short circuit currentduring the out-of-zone fault.

n the turns ratio of the CT

Rin the secondary internal resistance of the CT in ohms

Rm the resistance (maximum of Rin + Rm) of the CT secondary circuit in ohms

The current transformers must be able to force enough current to operate the IEDthrough the differential circuit during a fault condition inside the zone ofprotection. To ensure this, the knee point voltage Ukn should be at least two timeshigher than the stabilizing voltage Us.

The required knee point voltage Ukn of the current transformer is calculated usingthe formula

U Ukn s≥ ×2

GUID-4F7F301A-1573-4736-B740-622605DB0FFB V2 EN (Equation 49)

Ukn the knee point voltage

Us the stabilizing voltage

The factor two is used when no delay in the operating time of the protection in anysituation is acceptable. To prevent the knee point voltage from growing too high, itis advisable to use current transformers, the secondary winding resistance of whichis of the same size as the resistance of the measuring loop.

As the impedance of the IED alone is low, a stabilizing resistor is needed. Thevalue of the stabilizing resistor is calculated with the formula



RU

Is

s

rs

=

GUID-EA4FE2BC-4E93-4093-BD14-F20A4F33AEF2 V1 EN (Equation 50)

Rs the resistance of the stabilizing resistor

Us the stabilizing voltage of the IED

Irs the value of the Operate value setting in secondary amps.

The stabilizing resistor should be capable to dissipate high energy within a veryshort time; therefore, the wire wound-type resistor should be used. Because of thepossible CT inaccuracy, which might cause some current through the stabilizingresistor in a normal load situation, the rated power should be 25 W minimum.

If Ukn is high or the stabilizing voltage is low, a resistor with a higher power ratingis needed. Often resistor manufacturers allow 10 times rated power for 5 seconds.Thus the power of the resistor can be calculated with the equation

U

R

kn

s

2

10×

GUID-93E59545-7530-408D-8ECF-2D3D9CF76C13 V1 EN (Equation 51)

The actual sensitivity of the protection is affected by the IED setting, themagnetizing currents of the parallel connected CTs and the shunting effect of thevoltage-dependent resistor (VDR). The value of the primary current Iprim at whichthe IED operates at a certain setting can be calculated with the formula

I n I I m Iprim rs u m= × + + ×( )

GUID-2A742729-7244-4B1C-A4DF-404BDD3A68D9 V1 EN (Equation 52)

Iprim the primary current at which the protection is to start

n the turn ratio of the current transformer

Irs the value of the Operate value setting

Iu the leakage current flowing through the VDR at the Us voltage

m the number of current transformers included in the protection per phase (=4)

Im the magnetizing current per current transformer at the Us voltage

The Ie value given in many catalogs is the excitation current at the knee point

voltage. Assuming Ukn ≈ 2 x Us, the value of Im ≈Ie

2 gives an approximate valuefor Equation 52.

The selection of current transformers can be divided into procedures:



1. In principle, the highest through-fault should be known. However, when thenecessary data are not available, approximates can be used:• Small power transformers: Ikmax = 16 x In (corresponds to zk = 6% and

infinite grid)• Large power transformers: Ikmax = 12 x In (corresponds to zk = 8% and

infinite grid)• Generators and motors: Ikmax = 6 x In

Where In = rated current and zk = short circuit impedance of theprotected object

2. The rated primary current I1n of the CT has to be higher than the rated currentof the machine.The choice of the CT also specifies Rin.

3. The required Ukn is calculated with Equation 49. If the Ukn of the CT is nothigh enough, another CT has to be chosen. The value of the Ukn is given by themanufacturer in the case of Class X current transformers or it can be estimatedwith Equation 53.

4. The sensitivity Iprim is calculated with Equation 52. If the achieved sensitivityis sufficient, the present CT is chosen. If a better sensitivity is needed, a CTwith a bigger core is chosen.

If other than Class X CTs are used, an estimate for Ukn is calculated with the equation

U F I RS

Ikn n n in

n

n

= × × × +

0 8 2

22

.

GUID-AFA68232-5288-4220-845E-40347B691E29 V2 EN (Equation 53)

Fn the rated accuracy limit factor corresponding to the rated burden Sn

I2n the rated secondary current of the CT

Rin the secondary internal resistance of the CT

Sn the volt-amp rating of the CT

The formulas are based on choosing the CTs according to Equation49, which results an absolutely stable scheme. In some cases, it ispossible to achieve stability with knee point voltages lower thanstated in the formulas. The conditions in the network, however,have to be known well enough to ensure the stability.

1. If Uk ≥ 2 x Us, fast IED operation is secure.2. If Uk ≥ 1.5 x Us and < 2 x Us, IED operation can be slightly

prolonged and should be studied case by case.If Uk < 1.5 x Us, the IED operation is jeopardized. Another CThas to be chosen.



The need for the VDR depends on certain conditions.

First, voltage Umax, ignoring the CT saturation during the fault, is calculated withthe equation

UI

nR R R

I

nR

k inin m s

k insmax

max max= × + +( ) ≈ ×

GUID-CB54C30A-C69D-4C59-B9B3-44530319D1CE V1 EN (Equation 54)

Ikmaxin the maximum fault current inside the zone, in primary amps

n the turns ration of the CT

Rin the internal resistance of the CT in ohms

Rm the resistance of the longest loop of the CT secondary circuit, in ohms

Rs the resistance of the stabilized resistor, in ohms

Next, the peak voltage û, which includes the CT saturation, is estimated with theformula (given by P.Mathews, 1955)

û U U Ukn kn= −( )2 2 max

GUID-0FBE4CDF-8A7C-4574-8325-C61E61E0C55C V1 EN (Equation 55)

Ukn the knee point voltage of the CT

The VDR is recommended when the peak voltage û ≥ 2kV, which is the insulationlevel for which the IED is tested.

If Rs was smaller, the VDR could be avoided. However, the value of Rs depends onthe IED operation current and stabilizing voltage. Thus, either a higher setting mustbe used in the IED or the stabilizing voltage must be lowered.



4.3.4.8 Setting examples

Example 1

n

n2

m

u

s

GUID-AB960DE4-4DD2-4312-9921-0D6E7CD001AA V1 EN

Figure 207: Restricted earth-fault protection of a transformer

The data for the protected power transformer are:

Sn = 20 MVA

U2n = 11 kV

The longest distance of the secondary circuit is 50 m (the whole loop is 100 m) andthe area of the cross section is 10 mm2.

In = Sn / (√3 · Un) = 1050 A

Ikmax = 12 · In = 12600 A

In this example, the CT type is IHBF 12, the core size is 35 percent, the primarycurrent is 1200 A and the secondary current is 5 A.

Rin = 0.26 Ω (value given by the manufacturer).

Uk = 40 V (value given by the manufacturer).

Ie = 0.055 A (value given by the manufacturer).

Rm = 1.81 Ω/km · 2 · 0.05 km = 0.181 Ω ≈ 0.18 Ω



U V Vs =× +

≈12600 0 26 0 18

24023

( . . )

GUID-7AA079B9-4E11-48BD-A474-B7A06BA3976B V1 EN

According to the criterion, the value of Uk should be 2 · Us = 2 · 23 V = 46 V. Itdepends on if the stability of the scheme is achieved with Uk = 40 V. Otherwise, itis possible to choose a bigger core of 65 percent with:



Rm = 0.18 Ω

U V Vs =× +

≈12600 0 47 0 18

24034

( . . )

GUID-F7AF5A9B-A4F3-4714-94D2-022A54232F0E V1 EN

Uk = 2 · Us = 68 V (required value).

As mentioned earlier, Im = 0.5 · Ie gives a realistic value for Iprim in Equation 52. IfIu = 0 and Irs = m · 0.5 · Io, the value for the sensitivity is:

Iprim = n · m · Ie = 240 · 4 · 0.055 A ≈ 53 A

Irs = 4· 0.5 · 0.055 A = 0.11 A

The setting value can be calculated with:

OperatevalueI

I

A

A

rs

CT n

=

=

≈

_

.. %

2

0 11

52 2

GUID-C03C3B3E-E03F-41F3-B51A-A9AA161BC433 V1 EN

The resistance of the stabilizing resistor can be calculated:

Rs = Us / Irs = 34 V / 0.11 A ≈ 309 Ω

However, the sensitivity can be calculated more accurately when the actual valuesof Iu and Irs are known. The stabilizing resistor of the relay is chosen freely in theabove example and it is assumed that the resistor value is not fixed.



Example 2a

n

n

m

u

s

GUID-787D9DE6-961E-454A-B97A-FAFC6F9701F0 V1 EN

Figure 208: Restricted earth-fault protection of a generator

In the protected generator:

Sn = 8 MVA

Un = 6 kV.

In = 770 A

Ikmax = 6 · In = 6 · 770 A = 4620 A

In this example, the CT type is KOFD 12 A 21 with:

ICT_1n = 1000 A (value given by the manufacturer).

ICT_2n = 1 A (value given by the manufacturer).



Ie = 0.012 A (value given by the manufacturer).

If the length of the secondary circuit is 100 m (the whole loop is 200 m) and thearea of the cross section is 2.5 mm2:

Rm = 7.28 Ω/km · 2 · 0.1 km ≈ 1.46 Ω



The required knee-point voltage can be calculated using Equation 49.

Uk = 2 · ( 4620 A / 1000 ) · ( 15.3 + 1.46 ) ≈ 155 V.

The value 155 V is lower than the value 323 V, which means that the value of Uk ishigh enough.

As mentioned earlier, Im = 0.5 · Ie gives a realistic value for Iprim in Equation 52. IfIu = 0 and Irs = m · 0.5 · Ie, the value for the sensitivity is:

Iprim = n · m · Ie = 1000 · 4 · 0.012 A = 48 A ( ≈ 6 % x In).

Irs = 4 · 0.5 · 0.012 A = 0.024 A.


OperatevalueI

I

A

A

rs

CT n

=

=

≈

_

.. %

2

0 024

12 4

GUID-3873DFF7-8FB3-42B1-BF99-CE7D9D141F55 V1 EN

The resistance of the stabilizing resistor can now be calculated:

Rs = Us / Irs = 78 V / (2 · Ie) = 78 V / (2 · 0.012 A) = 3250 Ω.

Example 2bIn this example, Irs = 4 x 12 mA = 48 mA and Iu = 30 mA. This results in the sensitivity:

Iprim = n · ( Irs + Iu + m · Im ) = 1000 · (48 + 30 + 24) mA = 102 A


OperatevalueI

I

A

A

rs

CT n

=

=

≈

_

.. %

2

0 048

14 8

GUID-4373B1E0-46AB-401A-A76A-AD97B850D079 V1 EN

The resistance of the stabilizing resistor is now:

Rs = Us / Irs= 78 V / 48 mA ≈ 1630 Ω

In this example, the relay is of such a type that the stabilizing resistor can bechosen freely.

4.3.4.9 Signals

Table 317: HREFPDIF Input signals

Name Type Default DescriptionIDo SIGNAL 0 Differential current




Table 318: HREFPDIF Output signals


START BOOLEAN Start

4.3.4.10 Settings

Table 319: HREFPDIF Group settings

Parameter Values (Range) Unit Step Default DescriptionOperate value 1.0...50.0 %In 0.1 1.0 Low operate value, percentage of the

nominal current

Minimum operate time 40...300000 ms 1 40 Minimum operate time

Table 320: HREFPDIF Non group settings





Table 321: HREFPDIF Monitored data


operate time

HREFPDIF Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 322: HREFPDIF Technical data


measured: fn ±2 Hz



IFault = 2.0 x setOperate valueIFault = 10.0 x setOperate value

16 ms11 ms

21 ms13 ms

23 ms14 ms








1) Current before fault = 0.0, fn = 50 Hz, results based on statistical distribution of 1000 measurements2) Includes the delay of the signal output contact

4.4 Unbalance protection

4.4.1 Negative-sequence overcurrent protection NSPTOC





Negative-sequence overcurrentprotection

NSPTOC I2> 46


A070758 V1 EN



The negative-sequence overcurrent protection NSPTOC is used for increasingsensitivity to detect single-phase and phase-to-phase faults or unbalanced loads dueto, for example, broken conductors or unsymmetrical feeder voltages.

NSPTOC can also be used for detecting broken conductors.

The function is based on the measurement of the negative sequence current. In afault situation, the function starts when the negative sequence current exceeds theset limit. The operate time characteristics can be selected to be either definite time(DT) or inverse definite minimum time (IDMT). In the DT mode, the function



operates after a predefined operate time and resets when the fault currentdisappears. The IDMT mode provides current-dependent timer characteristics.




The operation of the negative-sequence overcurrent protection can be describedusing a module diagram. All the modules in the diagram are explained in the nextsections.

A070660 V1 EN

Figure 210: Functional module diagram. I2 represents negative phasesequence current.

Level detectorThe measured negative-sequence current is compared to the set Start value. If themeasured value exceeds the set Start value, the level detector activates the timermodule. If the ENA_MULT input is active, the set Start value is multiplied by theset Start value Mult.

The IED does not accept the Start value or Start value Mult settingif the product of the settings exceeds the Start value setting range.





4.4.1.5 Application

Since the negative sequence current quantities are not present during normal,balanced load conditions, the negative sequence overcurrent protection elementscan be set for faster and more sensitive operation than the normal phase-overcurrent protection for fault conditions occurring between two phases. Thenegative sequence overcurrent protection also provides a back-up protectionfunctionality for the feeder earth-fault protection in solid and low resistanceearthed networks.

The negative sequence overcurrent protection provides the back-up earth-faultprotection on the high voltage side of a delta-wye connected power transformer forearth faults taking place on the wye-connected low voltage side. If an earth faultoccurs on the wye-connected side of the power transformer, negative sequencecurrent quantities appear on the delta-connected side of the power transformer.

The most common application for the negative sequence overcurrent protection isprobably rotating machines, where negative sequence current quantities indicateunbalanced loading conditions (unsymmetrical voltages). Unbalanced loadingnormally causes extensive heating of the machine and can result in severe damageseven over a relatively short time period.

Multiple time curves and time multiplier settings are also available for coordinatingwith other devices in the system.

4.4.1.6 Signals

Table 323: NSPTOC Input signals

Name Type Default DescriptionI2 SIGNAL 0 Negative phase sequence current



Table 324: NSPTOC Output signals


START BOOLEAN Start



4.4.1.7 Settings

Table 325: NSPTOC Group settings









Table 326: NSPTOC Non group settings













Table 327: NSPTOC Monitored data


operate time

NSPTOC Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 328: NSPTOC Technical data


measured: fn ±2 Hz



IFault = 2 x set StartvalueIFault = 10 x set Startvalue

22 ms14 ms

24 ms16 ms

25 ms17 ms

Reset time < 40 ms






1) Negative sequence current before fault = 0.0, fn = 50 Hz, results based on statistical distribution of1000 measurements



Table 329: NSPTOC Technical revision history



C Step value changed from 0.05 to 0.01 for theTime multiplier setting



4.4.2 Phase discontinuity protection PDNSPTOC





Phase discontinuity protection PDNSPTOC I2/I1> 46PD


A070688 V1 EN



The phase discontinuity protection PDNSPTOC is used for detecting unbalancesituations caused by broken conductors.

The function starts and operates when the unbalance current I2/I1 exceeds the setlimit. To prevent faulty operation at least one phase current needs to be above theminimum level. PDNSPTOC operates with DT characteristic.

The function contains a blocking functionality. It is possible to block the functionoutput, timer or the function itself, if desired.



The operation of phase discontinuity protection can be described by using a modulediagram. All the modules in the diagram are explained in the next sections.



A070687 V2 EN

Figure 212: Functional module diagram. I1 and I2 represent positive andnegative phase sequence currents. I_A, I_B and I_C representphase currents.

I2/I1The I2/I1 module calculates the ratio of the negative and positive sequence current.It reports the calculated value to the level detector.

Level detectorThe level detector compares the calculated ratio of the negative- and positive-sequence currents to the set Start value. If the calculated value exceeds the set Startvalue and the min current check module has exceeded the value of Min phasecurrent, the level detector reports the exceeding of the value to the timer.

Min current checkThe min current check module checks whether the measured phase currents areabove the set Min phase current. At least one of the phase currents needs to beabove the set limit to enable the level detector module.


The timer calculates the start duration value START_DUR, which indicates thepercentage ratio of the start situation and the set operation time. The value isavailable in the monitored data view.

Blocking logicThere are three operation modes in the blocking functionality. The operation modesare controlled by the BLOCK input and the global setting "Configuration/System/Blocking mode" which selects the blocking mode. The BLOCK input can becontrolled by a binary input, a horizontal communication input or an internal signal



of the IED program. The influence of the BLOCK signal activation is preselectedwith the global setting Blocking mode.


4.4.2.5 Application

In three-phase distribution and subtransmission network applications the phasediscontinuity in one phase can cause an increase of zero-sequence voltage and shortovervoltage peaks and also oscillation in the corresponding phase.

PDNSPTOC is a three-phase protection with DT characteristic, designed fordetecting broken conductors in distribution and subtransmission networks. Thefunction is applicable for both overhead lines and underground cables.

The operation of PDNSPTOC is based on the ratio of the positive-sequence andnegative-sequence currents. This gives a better sensitivity and stability compared toplain negative-sequence current protection since the calculated ratio of positive-sequence and negative-sequence currents is relatively constant during load variations.

The unbalance of the network is detected by monitoring the negative-sequence andpositive-sequence current ratio, where the negative-sequence current value is I2 andI1 is the positive-sequence current value. The unbalance is calculated with theequation.

IratioI

I=

2

1


Broken conductor fault situation can occur in phase A in a feeder.

IECA070699 V2 EN

Figure 213: Broken conductor fault situation in phase A in a distribution orsubtransmission feeder



IECA070698 V1 EN

Figure 214: Three-phase current quantities during the broken conductor fault inphase A with the ratio of negative-sequence and positive-sequencecurrents

4.4.2.6 Signals

Table 330: PDNSPTOC Input signals

Name Type Default DescriptionI1 SIGNAL 0 Positive sequence current


I_A SIGNAL 0 Phase A current



BLOCK BOOLEAN 0=False Block signal for activating the blockingmode

Table 331: PDNSPTOC Output signals


START BOOLEAN Start

4.4.2.7 Settings

Table 332: PDNSPTOC Group settings

Parameter Values (Range) Unit Step Default DescriptionStart value 10...100 % 1 10 Start value




Table 333: PDNSPTOC Non group settings




Min phase current 0.05...0.30 xIn 0.01 0.10 Minimum phase current


Table 334: PDNSPTOC Monitored data


operate time

RATIO_I2_I1 FLOAT32 0.00...999.99 % Measured current ratioI2 / I1

PDNSPTOC Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 335: PDNSPTOC Technical data


measured: fn ±2 Hz

±2% of the set value

Start time < 70 ms

Reset time < 40 ms





4.4.3 Phase reversal protection PREVPTOC





Phase reversal protection PREVPTOC I2>> 46R




GUID-AA794558-EF3A-4E9A-AA39-BCE9FB7253FD V1 EN



The phase reversal protection PREVPTOC is used to detect the reversedconnection of the phases to a three-phase motor by monitoring the negative phasesequence current I2 of the motor.

PREVPTOC starts and operates when I2 exceeds the set limit. PREVPTOCoperates on definite time (DT) characteristics. PREVPTOC is based on thecalculated I2, and the function detects too high I2 values during the motor startup.The excessive I2 values are caused by incorrectly connected phases, which in turnmakes the motor rotate in the opposite direction.




The operation of phase reversal protection can be described with a modulediagram. All the modules in the diagram are explained in the next sections.

GUID-F0B4B5EF-8B3C-4967-9818-24DACE686FC8 V1 EN


Level detectorThe level detector compares the negative-sequence current to the set Start value. Ifthe I2 value exceeds the set Start value, the level detector sends an enabling signalto the timer module.

TimerOnce activated, the timer activates the START output. When the operation timerhas reached the set Operate delay time value, the OPERATE output is activated. If



the fault disappears before the module operates, the reset timer is activated. If thereset timer reaches the value of 200 ms, the operation timer resets and the STARToutput is deactivated.


4.4.3.5 Application

The rotation of a motor in the reverse direction is not a desirable operatingcondition. When the motor drives fans and pumps, for example, and the rotationdirection is reversed due to a wrong phase sequence, the driven process can bedisturbed and the flow of the cooling air of the motor can become reversed too.With a motor designed only for a particular rotation direction, the reversed rotationdirection can lead to an inefficient cooling of the motor due to the fan design.

In a motor, the value of the negative-sequence component of the phase currents isvery negligible when compared to the positive-sequence component of the currentduring a healthy operating condition of the motor. But when the motor is startedwith the phase connections in the reverse order, the magnitude of I2 is very high.So whenever the value of I2 exceeds the start value, the function detects the reverserotation direction and provides an operating signal that disconnects the motor fromthe supply.

4.4.3.6 Signals

Table 336: PREVPTOC Input signals

Name Type Default DescriptionI2 SIGNAL 0 Negative sequence current


Table 337: PREVPTOC Output signals


START BOOLEAN Start

4.4.3.7 Settings

Table 338: PREVPTOC Group settings





Table 339: PREVPTOC Non group settings




Table 340: PREVPTOC Monitored data


operate time

PREVPTOC Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 341: PREVTOC Technical data


measured: fn ±2 Hz




Reset time < 40 ms





1) Negative-sequence current before = 0.0, fn = 50 Hz, results based on statistical distribution of 1000measurements

2) Includes the delay of the signal output contact

4.4.4 Negative-sequence overcurrent protection for motorsMNSPTOC





Negative-sequence overcurrentprotection for motors

MNSPTOC I2>M 46M




GUID-5B6B4705-1EF3-4E12-B1A6-92A5D9D71218 V2 EN



The unbalance protection based on the negative-sequence overcurrent protectionfor motors MNSPTOC protects electric motors from phase unbalance. A smallvoltage unbalance can produce a large negative-sequence current flow in the motor.For example, a 5 percent voltage unbalance produces a stator negative-sequencecurrent of 30 percent of the full load current, which can severely heat the motor.MNSPTOC detects the large negative-sequence current and disconnects the motor.

The function contains a blocking functionality. It is possible to block the functionoutputs, timers or the function itself, if desired.



The operation of unbalance protection based on negative sequence current can bedescribed by using a module diagram. All the modules in the diagram are explainedin the next sections.

GUID-F890E844-B9C9-4E99-A51F-6EAB19B5239B V1 EN


Level detectorThe calculated negative-sequence current is compared to the Start value setting. Ifthe measured value exceeds the Start value setting, the function activates the timermodule.



TimerOnce activated, the timer activates the START output. Depending on the value ofthe set Operating curve type, the time characteristics are according to DT or IDMT.When the operation timer has reached the value set by Operate delay time in theDT mode or the maximum value defined by the inverse time curve, the OPERATEoutput is activated.

In a drop-off situation, that is, when the value of the negative-sequence currentdrops below the Start value setting, the reset timer is activated and the STARToutput resets after the time delay of Reset delay time for the DT characteristics. ForIDMT, the reset time depends on the curve type selected.

For the IDMT curves, it is possible to define minimum and maximum operatetimes with the Minimum operate time and Maximum operate time settings. TheMachine time Mult setting parameter corresponds to the machine constant, equal tothe I2

2t constant of the machine, as stated by the machine manufacturer. In casethere is a mismatch between the used CT and the protected motor's nominal currentvalues, it is possible to fit the IDMT curves for the protected motor using the Ratedcurrent setting.

The activation of the OPERATE output activates the BLK_RESTART output. Thedeactivation of the OPERATE output activates the cooling timer. The timer is set tothe value entered in the Cooling time setting. The BLK_RESTART output is keptactive until the cooling timer is exceeded. If the negative-sequence currentincreases above the set value during this period, the OPERATE output is activatedimmediately.

The T_ENARESTART output indicates the duration for which the BLK_RESTARToutput remains active, that is, it indicates the remaining time of the cooling timer.The value is available in the monitored data view.



MNSPTOC supports both DT and IDMT characteristics. The DT timercharacteristics can be selected with "ANSI Def. Time" or "IEC Def. Time" in theOperating curve type setting. The functionality is identical in both cases. When theDT characteristics are selected, the functionality is only affected by the Operatedelay time and Reset delay time settings.

The IED provides two user-programmable IDMT characteristics curves, "Inv.curve A" and "Inv. curve B".



Current-based inverse definite minimum time curve (IDMT)In inverse-time modes, the operate time depends on the momentary value of thecurrent: the higher the current, the shorter the operate time. The operate timecalculation or integration starts immediately when the current exceeds the set Startvalue and the START output is activated.

The OPERATE output of the component is activated when the cumulative sum ofthe integrator calculating the overcurrent situation exceeds the value set by theinverse time mode. The set value depends on the selected curve type and the settingvalues used.

The Minimum operate time and Maximum operate time settings define theminimum operate time and maximum operate time possible for the IDMT mode.For setting these parameters, a careful study of the particular IDMT curves isrecommended.

Inv. curve AThe inverse time equation for curve type A is:

t sk

I

Ir

[ ] =

2

2

GUID-D8A4A304-6C63-4BA4-BAEA-E7891504557A V1 EN (Equation 57)

t[s] Operate time in seconds

k Set Machine time Mult

I2 Negative-sequence current

Ir Set Rated current

If the negative-sequence current drops below the Start value setting, the reset timeis defined as:

t s ab

[ ] = ×

100

GUID-8BE4B6AC-FB61-4D30-B77B-3E599D5BAE81 V1 EN (Equation 58)

t[s] Reset time in seconds

a set Cooling time

b percentage of start time elapse (START_DUR)

When the reset period is initiated, the time for which START has been active issaved. Now, if the fault reoccurs, that is, the negative-sequence current rises abovethe set value during the reset period, the operate calculations are continued usingthe saved values. However, if the reset period elapses without a fault being



detected, the operate timer is reset and the saved values of start time andintegration are cleared.

Inv. curve BThe inverse time equation for curve type B is:

t sk

I

I

I

Ir

S

r

[ ] =

−

2

2 2

GUID-805DCB50-71D2-4721-830B-3343E1A5500B V1 EN (Equation 59)


k Machine time Mult

I2 Negative-sequence current

IS Set Start value

Ir Set Rated current

If the fault disappears, the negative-sequence current drops below the Start valuesetting and the START output is deactivated. However, the function does not resetinstantaneously, but instead it depends on the equation or the Cooling time setting.

The timer can be reset in two ways:

• With a drop in the negative-sequence current below start value, the subtractionin the denominator becomes negative and the cumulative sum starts todecrease. The decrease in the sum indicates the cooling of the machine and thecooling speed depends on the value of the negative-sequence current. If thesum reaches zero without a fault being detected, the accumulation stops andthe timer is reset.

• If the reset time set through the Cooling time setting elapses without a faultbeing detected, the timer is reset.

The reset period thus continues for a time equal to the Cooling time setting or untilthe operate time decreases to zero, whichever is less.

4.4.4.6 Application

In a three-phase motor, the conditions that can lead to unbalance are singlephasing, voltage unbalance from the supply and single-phase fault. The negativesequence current damages the motor during the unbalanced voltage condition, andtherefore the negative sequence current is monitored to check the unbalancecondition.

When the voltages supplied to an operating motor become unbalanced, the positive-sequence current remains substantially unchanged, but the negative-sequencecurrent flows due to the unbalance. For example, if the unbalance is caused by an



open circuit in any phase, a negative-sequence current flows and it is equal andopposite to the previous load current in a healthy phase. The combination ofpositive and negative-sequence currents produces phase currents approximately 1.7times the previous load in each healthy phase and zero current in the open phase.

The negative-sequence currents flow through the stator windings inducing negative-sequence voltage in the rotor windings. This can result in a high rotor current thatdamages the rotor winding. The frequency of the induced current is approximatelytwice the supply frequency. Due to skin effect, the induced current with afrequency double the supply frequency encounters high rotor resistance whichleads to excessive heating even with phase currents with value less than the ratedcurrent of the motor.

The negative-sequence impedance of induction or a synchronous motor isapproximately equal to the locked rotor impedance, which is approximately one-sixth of the normal motor impedance, considering that the motor has a locked-rotorcurrent of six times the rated current. Therefore, even a three percent voltageunbalance can lead to 18 percent stator negative sequence current in windings. Theseverity of this is indicated by a 30-40 percent increase in the motor temperaturedue to the extra current.

4.4.4.7 Signals

Table 342: MNSPTOC Input signals

Name Type Default DescriptionI2 SIGNAL 0 Negative sequence current


Table 343: MNSPTOC Output signals


START BOOLEAN Start

BLK_RESTART BOOLEAN Overheated machine reconnection blocking

4.4.4.8 Settings

Table 344: MNSPTOC Group settings


Operating curve type 5=ANSI Def. Time15=IEC Def. Time17=Inv. Curve A18=Inv. Curve B


Machine time Mult 5.0...100.0 0.1 5.0 Machine related time constant




Table 345: MNSPTOC Non group settings



Rated current 0.30...2.00 xIn 0.01 1.00 Rated current (Ir) of the machine (usedonly in the IDMT)

Maximum operate time 500000...7200000 ms 1000 1000000 Max operate time regardless of theinverse characteristic


Cooling time 5...7200 s 1 50 Time required to cool the machine



Table 346: MNSPTOC Monitored data


operate time

T_ENARESTART FLOAT32 0.00...7200.00 s Estimated time to resetof block restart

MNSPTOC Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 347: MNSPTOC Technical data


measured: fn ±2 Hz




Reset time < 40 ms






1) Negative-sequence current before = 0.0, fn = 50 Hz, results based on statistical distribution of 1000measurements

2) Includes the delay of the signal output contact3) Start value multiples in range of 1.10 to 5.00



4.5 Voltage protection

4.5.1 Three-phase overvoltage protection PHPTOV





Three-phase overvoltage protection PHPTOV 3U> 59


GUID-871D07D7-B690-48FD-8EA1-73A7169AE8BD V1 EN



The three-phase overvoltage protection PHPTOV is applied on power systemelements, such as generators, transformers, motors and power lines, to protect thesystem from excessive voltages that could damage the insulation and causeinsulation breakdown. The three-phase overvoltage function includes a settablevalue for the detection of overvoltage either in a single phase, two phases or threephases.

PHPTOV includes both definite time (DT) and inverse definite minimum time(IDMT) characteristics for the delay of the trip.




The operation of the three-phase overvoltage protection can be described using amodule diagram. All the modules in the diagram are explained in the next sections.



Phaseselection

logic

BLOCK

OPERATE

START

Leveldetector t

Timer

t

U_A_ABU_B_BCU_C_CA

Blockinglogic

GUID-D71B1772-3503-4150-B3FE-6FFD92DE5DB7 V2 EN


Level detectorThe fundamental frequency component of the measured three-phase voltages arecompared phase-wise to the set value of the Start value setting. If the measuredvalue is higher than the set value of the Start value setting, the level detectorenables the phase selection logic module. The Relative hysteresis setting can beused for preventing unnecessary oscillations if the input signal slightly differs fromthe Start value setting. After leaving the hysteresis area, the start condition has tobe fulfilled again and it is not sufficient for the signal to only return to thehysteresis area.

The Voltage selection setting is used for selecting phase-to-earth or phase-to-phasevoltages for protection.

For the voltage IDMT operation mode, the used IDMT curve equations containdiscontinuity characteristics. The Curve Sat relative setting is used for preventingundesired operation.

For a more detailed description of the IDMT curves and the use ofthe Curve Sat Relative setting, see the IDMT curve saturation of theover voltage protection section in this manual.

Phase selection logicIf the fault criteria are fulfilled in the level detector, the phase selection logicdetects the phase or phases in which the fault level is detected. If the number offaulty phases match with the set Num of start phases, the phase selection logicactivates the timer.

TimerOnce activated, the timer activates the START output. Depending on the value ofthe set Operating curve type, the time characteristics are selected according to DTor IDMT.

For a detailed description of the voltage IDMT curves, see theIDMT curves for overvoltage protection section in this manual.



When the operation timer has reached the value set by Operate delay time in theDT mode or the maximum value defined by the IDMT, the OPERATE output isactivated.

When the user-programmable IDMT curve is selected, the operate timecharacteristics are defined by the parameters Curve parameter A, Curve parameterB, Curve parameter C, Curve parameter D and Curve parameter E.

If a drop-off situation occurs, that is, a fault suddenly disappears before the operatedelay is exceeded, the reset state is activated. The behavior in the drop-off situationdepends on the selected operate time characteristics. If the DT characteristics areselected, the reset timer runs until the set Reset delay time value is exceeded. If thedrop-off situation exceeds the set Reset delay time, the timer is reset and theSTART output is deactivated.

When the IDMT operate time curve is selected, the functionality of the timer in thedrop-off state depends on the combination of the Type of reset curve and Resetdelay time settings.

Table 348: The reset time functionality when the IDMT operate time curve is selected

Type of reset curve Description of operation“Immediate” The operate timer is reset instantaneously when

drop-off occurs

“Def time reset” The operate timer is frozen during drop-off.Operate timer is reset after the set Reset delaytime is exceeded

“DT Lin decr rst” The operate timer value linearly decreasesduring the drop-off situation. The operate timer isreset after the set Reset delay time is exceeded



GUID-504A5E09-8D82-4B57-9B3A-2BAE7F84FC0D V2 EN

Figure 221: Behavior of different IDMT reset modes. The value for Type ofreset curve is “Def time reset”. Also other reset modes arepresented for the time integrator.

The Time multiplier setting is used for scaling the IDMT operate times.

The Minimum operate time setting parameter defines the minimum desired operatetime for IDMT. The setting is applicable only when the IDMT curves are used.

The Minimum operate time setting should be used with carebecause the operation time is according to the IDMT curve, butalways at least the value of the Minimum operate time setting. Formore information, see the IDMT curves for overvoltage protectionsection in this manual.




Blocking logicThere are three operation modes in the blocking functionality. The operation modesare controlled by the BLOCK input and the global setting Configuration/System/Blocking mode which selects the blocking mode. The BLOCK input can becontrolled by a binary input, a horizontal communication input or an internal signalof the IED program. The influence of the BLOCK input signal activation ispreselected with the global Blocking mode setting.


The “Freeze timers” mode of blocking has no effect during theinverse reset mode.


The operating curve types supported by PHPTOV are:

Table 349: Timer characteristics supported by IDMT operate curve types

Operating curve type(5) ANSI Def. Time

(15) IEC Def. Time

(17) Inv. Curve A

(18) Inv. Curve B

(19) Inv. Curve C

(20) Programmable

4.5.1.6 Application

Overvoltage in a network occurs either due to the transient surges on the networkor due to prolonged power frequency overvoltages. Surge arresters are used toprotect the network against the transient overvoltages, but the IED protectionfunction is used to protect against power frequency overvoltages.

The power frequency overvoltage may occur in the network due to contingenciessuch as:



• The defective operation of the automatic voltage regulator when the generatoris in isolated operation.

• Operation under manual control with the voltage regulator out of service. Asudden variation of load, in particular the reactive power component, gives riseto a substantial change in voltage because of the inherent large voltageregulation of a typical alternator.

• Sudden loss of load due to the tripping of outgoing feeders, leaving thegenerator isolated or feeding a very small load. This causes a sudden rise in theterminal voltage due to the trapped field flux and overspeed.

If a load sensitive to overvoltage remains connected, it leads to equipment damage.

It is essential to provide power frequency overvoltage protection, in the form oftime delayed element, either IDMT or DT to prevent equipment damage.

4.5.1.7 Signals

Table 350: PHPTOV Input signals

Name Type Default DescriptionU_A_AB SIGNAL 0 Phase to earth voltage A or phase to phase

voltage AB




Table 351: PHPTOV Output signals


START BOOLEAN Start



4.5.1.8 Settings

Table 352: PHPTOV Group settings

Parameter Values (Range) Unit Step Default DescriptionStart value 0.05...1.60 xUn 0.01 1.10 Start value



Operating curve type 5=ANSI Def. Time15=IEC Def. Time17=Inv. Curve A18=Inv. Curve B19=Inv. Curve C20=Programmable


Type of reset curve 1=Immediate2=Def time reset-1=DT Lin decr rst


Table 353: PHPTOV Non group settings












Curve Sat Relative 0.0...3.0 0.1 2.0 Tuning parameter to avoid curvediscontinuities

Voltage selection 1=phase-to-earth2=phase-to-phase

2=phase-to-phase Parameter to select phase or phase-to-phase voltages

Relative hysteresis 1.0...5.0 % 0.1 4.0 Relative hysteresis for operation




Table 354: PHPTOV Monitored data


operate time

PHPTOV Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 355: PHPTOV Technical data

Characteristic ValueOperation accuracy Depending on the frequency of the voltage

measured: fn ±2 Hz

±1.5% of the set value or ±0.002 x Un


UFault = 1.1 x set Startvalue 22 ms 24 ms 26 ms

Reset time < 40 ms

Reset ratio Depends of the set Relative hysteresis





1) Start value = 1.0 x Un, Voltage before fault = 0.9 x Un, fn = 50 Hz, overvoltage in one phase-to-phase with nominal frequency injected from random phase angle, results based on statisticaldistribution of 1000 measurements

2) Includes the delay of the signal output contact3) Maximum Start value = 1.20 x Un, Start value multiples in range of 1.10 to 2.00


Table 356: PHPTOV Technical revision history





4.5.2 Three-phase undervoltage protection PHPTUV





Three-phase undervoltage protection PHPTUV 3U< 27


GUID-B4A78A17-67CA-497C-B2F1-BC4F1DA415B6 V1 EN



The three-phase undervoltage protection PHPTUV is used to disconnect from thenetwork devices, for example electric motors, which are damaged when subjectedto service under low voltage conditions. PHPTUV includes a settable value for thedetection of undervoltage either in a single phase, two phases or three phases.




The operation of the three-phase undervoltage protection can be described using amodule diagram. All the modules in the diagram are explained in the next sections.

GUID-21DCE3FD-C5A0-471A-AB93-DDAB4AE93116 V1 EN




Level detectorThe fundamental frequency component of the measured three phase voltages arecompared phase-wise to the set Start value. If the measured value is lower than theset value of the Start value setting, the level detector enables the phase selectionlogic module. The Relative hysteresis setting can be used for preventingunnecessary oscillations if the input signal slightly varies above or below the Startvalue setting. After leaving the hysteresis area, the pickup condition has to befulfilled again and it is not sufficient for the signal to only return back to thehysteresis area.

The Voltage selection setting is used for selecting the phase-to-earth or phase-to-phase voltages for protection.

For the voltage IDMT mode of operation, the used IDMT curve equations containdiscontinuity characteristics. The Curve Sat relative setting is used for preventingunwanted operation.

For more detailed description on IDMT curves and usage of CurveSat Relative setting, see the IDMT curves for under voltageprotection section in this manual.

The level detector contains a low-level blocking functionality for cases where oneof the measured voltages is below the desired level. This feature is useful whenunnecessary starts and operates are wanted to avoid during, for example, anautoreclose sequence. The low-level blocking is activated by default (Enable blockvalue is set to "True") and the blocking level can be set with the Voltage blockvalue setting.

Phase selection logicIf the fault criteria are fulfilled in the level detector, the phase selection logicdetects the phase or phases in which the fault level is detected. If the number offaulty phases match with the set Num of start phases, the phase selection logicactivates the timer.

TimerOnce activated, the timer activates the START output. Depending on the value ofthe set Operating curve type, the time characteristics are selected according to DTor IDMT.

For a detailed description of the voltage IDMT curves, see theIDMT curves for under voltage protection section in this manual.

When the operation timer has reached the value set by Operate delay time in theDT mode or the maximum value defined by the IDMT, the OPERATE output isactivated.



When the user-programmable IDMT curve is selected, the operate timecharacteristics are defined by the parameters Curve parameter A, Curve parameterB, Curve parameter C, Curve parameter D and Curve parameter E.

If a drop-off situation occurs, that is, a fault suddenly disappears before the operatedelay is exceeded, the reset state is activated. The behavior in the drop-off situationdepends on the selected operate time characteristics. If the DT characteristics areselected, the reset timer runs until the set Reset delay time value is exceeded. If thedrop-off situation exceeds the set Reset delay time, the timer is reset and theSTART output is deactivated.

When the IDMT operate time curve is selected, the functionality of the timer in thedrop-off state depends on the combination of the Type of reset curve and Resetdelay time settings.

Table 357: The reset time functionality when the IDMT operate time curve is selected

Type of reset curve Description of operation“Immediate” The operate timer is reset instantaneously when

drop-off occurs

“Def time reset” The operate timer is frozen during drop-off.Operate timer is reset after the set Reset delaytime is exceeded

“DT Lin decr rst” The operate timer value linearly decreasesduring the drop-off situation. The operate timer isreset after the set Reset delay time is exceeded



Example

GUID-111E2F60-2BFC-4D9B-B6C3-473F7689C142 V2 EN

Figure 224: Behavior of different IDMT reset modes. The value for Type ofreset curve is “Def time reset”. Also other reset modes arepresented for the time integrator.

The Time multiplier setting is used for scaling the IDMT operate times.

The Minimum operate time setting parameter defines the minimum desired operatetime for IDMT. The setting is applicable only when the IDMT curves are used.

The Minimum operate time setting should be used with carebecause the operation time is according to the IDMT curve, butalways at least the value of the Minimum operate time setting. Formore information, see the IDMT curves for overcurrent protectionsection in this manual.




Blocking logicThere are three operation modes in the blocking functionality. The operation modesare controlled by the BLOCK input and the global setting Configuration/System/Blocking mode which selects the blocking mode. The BLOCK input can becontrolled by a binary input, a horizontal communication input or an internal signalof the IED program. The influence of the BLOCK input signal activation ispreselected with the global Blocking mode setting.


The “Freeze timers” mode of blocking has no effect during the“Inverse reset” mode.


The operating curve types supported by PHPTUV are:

Table 358: Supported IDMT operate curve types

Operating curve type(5) ANSI Def. Time

(15) IEC Def. Time

(21) Inv. Curve A

(22) Inv. Curve B

(23) Programmable

4.5.2.6 Application

PHPTUV is applied to power system elements, such as generators, transformers,motors and power lines, to detect low voltage conditions. Low voltage conditionsare caused by abnormal operation or a fault in the power system. PHPTUV can beused in combination with overcurrent protections. Other applications are thedetection of a no-voltage condition, for example before the energization of a highvoltage line, or an automatic breaker trip in case of a blackout. PHPTUV is alsoused to initiate voltage correction measures, such as insertion of shunt capacitorbanks, to compensate for a reactive load and thereby to increase the voltage.



PHPTUV can be used to disconnect from the network devices, such as electricmotors, which are damaged when subjected to service under low voltageconditions. PHPTUV deals with low voltage conditions at power system frequency.Low voltage conditions can be caused by:

• Malfunctioning of a voltage regulator or incorrect settings under manualcontrol (symmetrical voltage decrease)

• Overload (symmetrical voltage decrease)• Short circuits, often as phase-to-earth faults (unsymmetrical voltage increase).

PHPTUV prevents sensitive equipment from running under conditions that couldcause overheating and thus shorten their life time expectancy. In many cases,PHPTUV is a useful function in circuits for local or remote automation processesin the power system.

4.5.2.7 Signals

Table 359: PHPTUV Input signals


voltage AB




Table 360: PHPTUV Output signals


START BOOLEAN Start

4.5.2.8 Settings

Table 361: PHPTUV Group settings




Operating curve type 5=ANSI Def. Time15=IEC Def. Time21=Inv. Curve A22=Inv. Curve B23=Programmable


Type of reset curve 1=Immediate2=Def time reset-1=DT Lin decr rst




Table 362: PHPTUV Non group settings












Curve Sat Relative 0.0...3.0 0.1 2.0 Tuning parameter to avoid curvediscontinuities

Voltage block value 0.05...1.00 xUn 0.01 0.20 Low level blocking for undervoltage mode

Enable block value 0=False1=True

1=True Enable internal blocking

Voltage selection 1=phase-to-earth2=phase-to-phase

2=phase-to-phase Parameter to select phase or phase-to-phase voltages



Table 363: PHPTUV Monitored data


operate time

PHPTUV Enum 1=on2=blocked3=test4=test/blocked5=off

Status




Table 364: PHPTUV Technical data


measured: fn ±2 Hz




Reset time < 40 ms

Reset ratio Depends on the set Relative hysteresis





1) Start value = 1.0 x Un, Voltage before fault = 1.1 x Un, fn = 50 Hz, undervoltage in one phase-to-phase with nominal frequency injected from random phase angle, results based on statisticaldistribution of 1000 measurements

2) Includes the delay of the signal output contact3) Minimum Start value = 0.50, Start value multiples in range of 0.90 to 0.20


Table 365: PHPTUV Technical revision history



4.5.3 Residual overvoltage protection ROVPTOV





Residual overvoltage protection ROVPTOV Uo> 59G


A070766 V3 EN





The residual overvoltage protection ROVPTOV is used in distribution networkswhere the residual overvoltage can reach non-acceptable levels in, for example,high impedance earthing.

The function starts when the residual voltage exceeds the set limit. ROVPTOVoperates with the definite time (DT) characteristic.




The operation of residual overvoltage protection can be described by using amodule diagram. All the modules in the diagram are explained in the next sections.

A070748 V2 EN

Figure 226: Functional module diagram. Uo represents the residual voltage.

Level detectorThe residual voltage can be selected with the Uo signal Sel setting. The selectableoptions are "Measured Uo" and "Calculated Uo". The residual voltage is comparedto the set Start value. If the value exceeds the set Start value, the level detectorsends an enable signal to the timer.







4.5.3.5 Application

ROVPTOV is designed to be used for earth-fault protection in isolated neutral,resistance earthed or reactance earthed systems. In compensated networks, startingof the function can be used to control the switching device of the neutral resistor.The function can also be used for the back-up protection of feeders for busbarprotection when a more dedicated busbar protection would not be justified.

In compensated and isolated neutral systems, the system neutral voltage, that is, theresidual voltage, increases in case of any fault connected to earth. Depending onthe type of the fault and the fault resistance, the residual voltage reaches differentvalues. The highest residual voltage, equal to the phase-to-earth voltage, isachieved for a single-phase earth fault. The residual voltage increasesapproximately the same amount in the whole system and does not provide anyguidance in finding the faulty component. Therefore, this function is often used asa backup protection or as a release signal for the feeder earth-fault protection.

The protection can also be used for the earth-fault protection of generators andmotors and for the unbalance protection of capacitor banks.

The residual voltage can be calculated internally based on the measurement of thethree-phase voltage. This voltage can also be measured by a single-phase voltagetransformer, located between a transformer star point and earth, or by using an open-delta connection of three single-phase voltage transformers.

4.5.3.6 Signals

Table 366: ROVPTOV Input signals

Name Type Default DescriptionUo SIGNAL 0 Residual voltage




Table 367: ROVPTOV Output signals


START BOOLEAN Start

4.5.3.7 Settings

Table 368: ROVPTOV Group settings

Parameter Values (Range) Unit Step Default DescriptionStart value 0.010...1.000 xUn 0.001 0.030 Residual overvoltage start value


Table 369: ROVPTOV Non group settings




Uo signal Sel 1=Measured Uo2=Calculated Uo

1=Measured Uo Selection for used Uo signal


Table 370: ROVPTOV Monitored data


operate time

ROVPTOV Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 371: ROVPTOV Technical data


measured: fn ±2 Hz












1) Residual voltage before fault = 0.0 x Un, fn = 50 Hz, residual voltage with nominal frequency injectedfrom random phase angle, results based on statistical distribution of 1000 measurements



Table 372: ROVPTOV Technical revision history

Technical revision ChangeB Added a setting parameter for the "Measured

Uo" or "Calculated Uo" selection

4.5.4 Negative-sequence overvoltage protection NSPTOV





Negative-sequence overvoltageprotection

NSPTOV U2> 47O-


GUID-F94BCCE8-841F-405C-B659-3EF26F959557 V1 EN



The negative-sequence overvoltage protection NSPTOV is used to detect negativesequence overvoltage conditions. NSPTOV is used for the protection of machines.

The function starts when the negative sequence voltage exceeds the set limit.NSPTOV operates with the definite time (DT) characteristics.






The operation of the negative-sequence overvoltage protection can be describedusing a module diagram. All the modules in the diagram are explained in the nextsections.

GUID-0014077D-EEA8-4781-AAC7-AFDBAAF415F4 V1 EN

Figure 228: Functional module diagram. U2 is used for representing negativephase sequence voltage.

Level detectorThe calculated negative-sequence voltage is compared to the set Start value setting.If the value exceeds the set Start value, the level detector enables the timer.

TimerOnce activated, the timer activates the START output. The time characteristic isaccording to DT. When the operation timer has reached the value set by Operatedelay time, the OPERATE output is activated if the overvoltage condition persists.If the negative-sequence voltage normalizes before the module operates, the resettimer is activated. If the reset timer reaches the value set by Reset delay time, theoperate timer resets and the START output is deactivated.



The Blocking mode setting has three blocking methods. In the "Freeze timers"mode, the operation timer is frozen to the prevailing value. In the "Block all"mode, the whole function is blocked and the timers are reset. In the "Block



OPERATE output" mode, the function operates normally but the OPERATE outputis not activated.

4.5.4.5 Application

A continuous or temporary voltage unbalance can appear in the network for variousreasons. The voltage unbalance mainly occurs due to broken conductors orasymmetrical loads and is characterized by the appearance of a negative-sequencecomponent of the voltage. In rotating machines, the voltage unbalance results in acurrent unbalance, which heats the rotors of the machines. The rotating machines,therefore, do not tolerate a continuous negative-sequence voltage higher thantypically 1-2 percent x Un.

The negative-sequence component current I2, drawn by an asynchronous or asynchronous machine, is linearly proportional to the negative-sequence componentvoltage U2. When U2 is P% of Un, I2 is typically about 5 x P% x In.

The negative-sequence overcurrent NSPTOC blocks are used to accomplish aselective protection against the voltage and current unbalance for each machineseparately. Alternatively, the protection can be implemented with the NSPTOVfunction, monitoring the voltage unbalance of the busbar.

If the machines have an unbalance protection of their own, the NSPTOV operationcan be applied as a backup protection or it can be used as an alarm. The latter canbe applied when it is not required to trip loads tolerating voltage unbalance betterthan the rotating machines.

If there is a considerable degree of voltage unbalance in the network, the rotatingmachines should not be connected to the network at all. This logic can beimplemented by inhibiting the closure of the circuit breaker if the NSPTOVoperation has started. This scheme also prevents connecting the machine to thenetwork if the phase sequence of the network is not correct.

An appropriate value for the setting parameter Voltage start value is approximately3 percent of Un. A suitable value for the setting parameter Operate delay timedepends on the application. If the NSPTOV operation is used as backup protection,the operate time should be set in accordance with the operate time of NSPTOCused as main protection. If the NSPTOV operation is used as main protection, theoperate time should be approximately one second.

4.5.4.6 Signals

Table 373: NSPTOV Input signals

Name Type Default DescriptionU2 SIGNAL 0 Negative phase sequence voltage




Table 374: NSPTOV Output signals


START BOOLEAN Start

4.5.4.7 Settings

Table 375: NSPTOV Group settings



Table 376: NSPTOV Non group settings





Table 377: NSPTOV Monitored data


operate time

NSPTOV Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 378: NSPTOV Technical data


measured: fn ±2 Hz

±1.5% of the set value or ±0.002 × Un


UFault = 1.1 × set StartvalueUFault = 2.0 × set Startvalue

33 ms24 ms

35 ms26 ms

37 ms28 ms

Reset time < 40 ms




Characteristic ValueReset ratio Typical 0.96



Suppression of harmonics DFT: -50 dB at f = n × fn, where n = 2, 3, 4, 5,…

1) Negative-sequence voltage before fault = 0.0 × Un, fn = 50 Hz, negative-sequence overvoltage withnominal frequency injected from random phase angle, results based on statistical distribution of1000 measurements



Table 379: NSPTOV Technical revision history

Technical revision ChangeB Internal change

4.5.5 Positive-sequence undervoltage protection PSPTUV





Positive-sequence undervoltageprotection

PSPTUV U1< 47U+


GUID-24EBDE8B-E1FE-47B0-878B-EBEC13A27CAC V1 EN



The positive-sequence undervoltage protection PSPTUV is used to detect positive-sequence undervoltage conditions. PSPTUV is used for the protection of smallpower generation plants. The function helps in isolating an embedded plant from afault line when the fault current fed by the plant is too low to start an overcurrentfunction but high enough to maintain the arc. Fast isolation of all the fault currentsources is necessary for a successful autoreclosure from the network-end circuitbreaker.

The function starts when the positive-sequence voltage drops below the set limit.PSPTUV operates with the definite time (DT) characteristics.






The operation of the positive-sequence undervoltage protection can be describedusing a module diagram. All the modules in the diagram are explained in the nextsections.

GUID-F1E58B1E-03CB-4A3C-BD1B-F809420397ED V1 EN

Figure 230: Functional module diagram. U1 is used for representing positivephase sequence voltage.

Level detectorThe calculated positive-sequence voltage is compared to the set Start value setting.If the value drops below the set Start value, the level detector enables the timer.The Relative hysteresis setting can be used for preventing unnecessary oscillationsif the input signal slightly varies from the Start value setting. After leaving thehysteresis area, the start condition has to be fulfilled again and it is not sufficientfor the signal to only return to the hysteresis area.

TimerOnce activated, the timer activates the START output. The time characteristic isaccording to DT. When the operation timer has reached the value set by Operatedelay time, the OPERATE output is activated if the undervoltage condition persists.If the positive-sequence voltage normalizes before the module operates, the resettimer is activated. If the reset timer reaches the value set by Reset delay time, theoperate timer resets and the START output is deactivated.


Blocking logicThere are three operation modes in the blocking functionality. The operation modesare controlled by the BLOCK input and the global setting "Configuration/System/



Blocking mode" which selects the blocking mode. The BLOCK input can becontrolled by a binary input, a horizontal communication input or an internal signalof the IED program. The influence of the BLOCK signal activation is preselectedwith the global setting Blocking mode.


4.5.5.5 Application

PSPTUV can be applied for protecting a power station used for embeddedgeneration when network faults like short circuits or phase-to-earth faults in atransmission or a distribution line cause a potentially dangerous situations for thepower station. A network fault can be dangerous for the power station for variousreasons. The operation of the protection can cause an islanding condition, alsocalled a loss-of-mains condition, in which a part of the network, that is, an islandfed by the power station, is isolated from the rest of the network. There is then arisk of an autoreclosure taking place when the voltages of different parts of thenetwork do not synchronize, which is a straining incident for the power station.Another risk is that the generator can lose synchronism during the network fault. Asufficiently fast trip of the utility circuit breaker of the power station can avoidthese risks.

The lower the three-phase symmetrical voltage of the network is, the higher is theprobability that the generator loses the synchronism. The positive-sequence voltageis also available during asymmetrical faults. It is a more appropriate criterion fordetecting the risk of loss of synchronism than, for example, the lowest phase-to-phase voltage.

Analyzing the loss of synchronism of a generator is rather complicated and requiresa model of the generator with its prime mover and controllers. The generator canbe able to operate synchronously even if the voltage drops by a few tens of percentfor some hundreds of milliseconds. The setting of PSPTUV is thus determined bythe need to protect the power station from the risks of the islanding conditionssince that requires a higher setting value.

The loss of synchronism of a generator means that the generator is unable tooperate as a generator with the network frequency but enters into an unstablecondition in which it operates by turns as a generator and a motor. Such a conditionstresses the generator thermally and mechanically. This kind of loss ofsynchronism should not be mixed with the one between an island and the utilitynetwork. In the islanding situation, the condition of the generator itself is normalbut the phase angle and the frequency of the phase-to-phase voltage can bedifferent from the corresponding voltage in the rest of the network. The island canhave a frequency of its own relatively fast when fed by a small power station with alow inertia.



PSPTUV complements other loss-of-grid protection principles based on thefrequency and voltage operation.

Motor stalling and failure to start can lead to a continuous undervoltage. The positive-sequence undervoltage is used as a backup protection against the motor stallcondition.

4.5.5.6 Signals

Table 380: PSPTUV Input signals

Name Type Default DescriptionU1 SIGNAL 0 Positive phase sequence voltage


Table 381: PSPTUV Output signals


START BOOLEAN Start

4.5.5.7 Settings

Table 382: PSPTUV Group settings



Voltage block value 0.01...1.00 xUn 0.01 0.20 Internal blocking level

Enable block value 0=False1=True

1=True Enable Internal Blocking

Table 383: PSPTUV Non group settings








Table 384: PSPTUV Monitored data


operate time

PSPTUV Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 385: PSPTUV Technical data


measured: fn ±2 Hz



UFault = 0.99 x set StartvalueUFault = 0.9 x set Startvalue

51 ms43 ms

53 ms45 ms

54 ms46 ms

Reset time < 40 ms

Reset ratio Depends of the set Relative hysteresis




1) Start value = 1.0 x Un, Positive sequence voltage before fault = 1.1 x Un, fn = 50 Hz, positivesequence undervoltage with nominal frequency injected from random phase angle, results based onstatistical distribution of 1000 measurements



Table 386: PSPTUV Technical revision history

Technical revision ChangeB -



4.6 Frequency protection

4.6.1 Frequency protection FRPFRQ





Frequency protection FRPFRQ f>/f<, df/dt 81O/81U, 81R


GUID-744529D8-E976-4AFD-AA77-85D6ED2C3B70 V1 EN



The frequency protection FRPFRQ is used to protect network components againstabnormal frequency conditions.

The function provides basic overfrequency, underfrequency and frequency rate-of-change protection. Additionally, it is possible to use combined criteria to achieveeven more sophisticated protection schemes for the system.




The operation of the frequency protection function can be described using amodule diagram. All the modules in the diagram are explained in the next sections.



F

BLOCK

Operate logic

Freq>/<detection

df/dtdetection

Blockinglogic

START

ST_FRG

ST_UFRQST_OFRQ

OPERATE

OPR_FRG

OPR_UFRQOPR_OFRQ

dF/dt

GUID-76692C3F-8B09-4C69-B598-0288CB946300 V1 EN


Freq>/< detectionThe frequency detection module includes an overfrequency or underfrequencydetection based on the Operation mode setting.

In the “Freq>” mode, the measured frequency is compared to the set Start valueFreq>. If the measured value exceeds the set value of the Start value Freq>setting, the module reports the exceeding of the value to the operate logic module.

In the “Freq<” mode, the measured frequency is compared to the set Start valueFreq<. If the measured value is lower than the set value of the Start value Freq<setting, the module reports the value to the operate logic module.

df/dt detectionThe frequency gradient detection module includes a detection for a positive ornegative rate-of-change (gradient) of frequency based on the set Start value df/dtvalue. The negative rate-of-change protection is selected when the set value isnegative. The positive rate-of-change protection is selected when the set value ispositive. When the frequency gradient protection is selected and the gradientexceeds the set Start value df/dt value, the module reports the exceeding of thevalue to the operate logic module.

The IED does not accept the set value "0.00" for the Start value df/dt setting.

Operate logicThis module is used for combining different protection criteria based on thefrequency and the frequency gradient measurement to achieve a more sophisticatedbehavior of the function. The criteria are selected with the Operation mode setting.



Table 387: Operation modes for operation logic

Operation mode DescriptionFreq< The function operates independently as the

underfrequency ("Freq<") protection function.When the measured frequency is below the setvalue of the Start value Freq< setting, themodule activates the START and STR_UFRQoutputs. The time characteristic is according toDT. When the operation timer has reached thevalue set by the Operate Tm Freq setting, theOPERATE and OPR_UFRQ outputs are activated.If the frequency restores before the moduleoperates, the reset timer is activated. If the timerreaches the value set by the Reset delay TmFreq setting, the operate timer resets and theSTART and STR_UFRQ outputs are deactivated.

Freq> The function operates independently as theoverfrequency ("Freq>") protection function.When the measured frequency exceeds the setvalue of the Start value Freq> setting, themodule activates the START and STR_OFRQoutputs. The time characteristic is according toDT. When the operation timer has reached thevalue set by the Operate Tm Freq setting, theOPERATE and OPR_OFRQ outputs are activated.If the frequency restores before the moduleoperates, the reset timer is activated. If the timerreaches the value set by the Reset delay TmFreq setting, the operate timer resets and theSTART and STR_OFRQ outputs are deactivated.

df/dt The function operates independently as thefrequency gradient ("df/dt"), rate-of-change,protection function. When the frequency gradientexceeds the set value of the Start value df/dtsetting, the module activates the START andSTR_FRG outputs. The time characteristic isaccording to DT. When the operation timer hasreached the value set by the Operate Tm df/dtsetting, the OPERATE and OPR_FRG outputs areactivated. If the frequency gradient restoresbefore the module operates, the reset timer isactivated. If the timer reaches the value set bythe Reset delay Tm df/dt setting, the operatetimer resets and the START and STR_FRGoutputs are deactivated.




Operation mode DescriptionFreq< + df/dt A consecutive operation is enabled between the

protection methods. When the measuredfrequency is below the set value of the Startvalue Freq< setting, the frequency gradientprotection is enabled. After the frequency hasdropped below the set value, the frequencygradient is compared to the set value of the Startvalue df/dt setting. When the frequency gradientexceeds the set value, the module activates theSTART and STR_FRG outputs. The timecharacteristic is according to DT. When theoperation timer has reached the value set by theOperate Tm df/dt setting, the OPERATE andOPR_FRG outputs are activated. If the frequencygradient restores before the module operates,the reset timer is activated. If the timer reachesthe value set by the Reset delay Tm df/dt setting,the operate timer resets and the START andSTR_FRG outputs are deactivated. TheOPR_UFRQ output is not active when thisoperation mode is used.




Operation mode DescriptionFreq> + df/dt A consecutive operation is enabled between the

protection methods. When the measuredfrequency exceeds the set value of the Startvalue Freq> setting, the frequency gradientprotection is enabled. After the frequencyexceeds the set value, the frequency gradient iscompared to the set value of the Start value df/dtsetting. When the frequency gradient exceedsthe set value, the module activates the STARTand STR_FRG outputs. The time characteristic isaccording to DT. When the operation timer hasreached the value set by the Operate Tm df/dtsetting, the OPERATE and OPR_FRG outputs areactivated. If the frequency gradient restoresbefore the module operates, the reset timer isactivated. If the timer reaches the value set bythe Reset delay Tm df/dt setting, the operatetimer resets and the START and STR_FRGoutputs are deactivated. The OPR_OFRQ outputis not active when this operation mode is used.

Freq< OR df/dt A parallel operation between the protectionmethods is enabled. The START output isactivated when either of the measured values ofthe protection module exceeds its set value.Detailed information about the active module isavailable at the STR_UFRQ and STR_FRGoutputs. The shortest operate delay time fromthe set Operate Tm Freq or Operate Tm df/dt isdominant regarding the OPERATE output. Thetime characteristic is according to DT. Thecharacteristic that activates the OPERATE outputcan be seen from the OPR_UFRQ or OPR_FRGoutput. If the frequency gradient restores beforethe module operates, the reset timer is activated.If the timer reaches the value set by the Resetdelay Tm df/dt setting, the operate timer resetsand the STR_FRG output is deactivated. If thefrequency restores before the module operates,the reset timer is activated. If the timer reachesthe value set by the Reset delay Tm Freqsetting, the operate timer resets and theSTR_UFRQ output is deactivated.




Operation mode DescriptionFreq> OR df/dt A parallel operation between the protection

methods is enabled. The START output isactivated when either of the measured values ofthe protection module exceeds its set value. Adetailed information from the active module isavailable at the STR_OFRQ and STR_FRGoutputs. The shortest operate delay time fromthe set Operate Tm Freq or Operate Tm df/dt isdominant regarding the OPERATE output. Thetime characteristic is according to DT. Thecharacteristic that activates the OPERATE outputcan be seen from the OPR_OFRQ or OPR_FRGoutput. If the frequency gradient restores beforethe module operates, the reset timer is activated.If the timer reaches the value set by the Resetdelay Tm df/dt setting, the operate timer resetsand the STR_FRG output is deactivated. If thefrequency restores before the module operates,the reset timer is activated. If the timer reachesthe value set by the Reset delay Tm Freqsetting, the operate timer resets and theSTR_UFRQ output is deactivated.

The module calculates the start duration value which indicates the percentage ratioof the start situation and set operate time (DT). The start duration is availableaccording to the selected value of the Operation mode setting.

Table 388: Start duration value

Operation mode in use Available start duration valueFreq< ST_DUR_UFRQ

Freq> ST_DUR_OFRQ

df/dt ST_DUR_FRG

The combined start duration START_DUR indicates the maximum percentage ratioof the active protection modes. The values are available via the Monitored data view.





4.6.1.5 Application

The frequency protection function uses the positive phase-sequence voltage tomeasure the frequency reliably and accurately.

The system frequency stability is one of the main principles in the distribution andtransmission network maintenance. To protect all frequency-sensitive electricalapparatus in the network, the departure from the allowed band for a safe operationshould be inhibited.

The overfrequency protection is applicable in all situations where high levels of thefundamental frequency of a power system voltage must be reliably detected. Thehigh fundamental frequency in a power system indicates an unbalance betweenproduction and consumption. In this case, the available generation is too largecompared to the power demanded by the load connected to the power grid. Thiscan occur due to a sudden loss of a significant amount of load or due to failures inthe turbine governor system. If the situation continues and escalates, the powersystem loses its stability.

The underfrequency is applicable in all situations where a reliable detection of alow fundamental power system voltage frequency is needed. The low fundamentalfrequency in a power system indicates that the generated power is too low to meetthe demands of the load connected to the power grid.

The underfrequency can occur as a result of the overload of generators operating inan isolated system. It can also occur as a result of a serious fault in the powersystem due to the deficit of generation when compared to the load. This can happendue to a fault in the grid system on the transmission lines that link two parts of thesystem. As a result, the system splits into two with one part having the excess loadand the other part the corresponding deficit.

The frequency gradient is applicable in all the situations where the change of thefundamental power system voltage frequency should be detected reliably. Thefrequency gradient can be used for both increasing and decreasing the frequencies.This function provides an output signal suitable for load shedding, generatorshedding, generator boosting, set point change in sub-transmission DC systems andgas turbine startup. The frequency gradient is often used in combination with a lowfrequency signal, especially in smaller power systems where the loss of a largegenerator requires quick remedial actions to secure the power system integrity. Insuch situations, the load shedding actions are required at a rather high frequencylevel. However, in combination with a large negative frequency gradient, theunderfrequency protection can be used at a high setting.



4.6.1.6 Signals

Table 389: FRPFRQ Input signals

Name Type Default DescriptionF SIGNAL 0 Measured frequency

dF/dt SIGNAL 0 Rate of change of frequency


Table 390: FRPFRQ Output signals


OPR_OFRQ BOOLEAN Operate signal for overfrequency

OPR_UFRQ BOOLEAN Operate signal for underfrequency

OPR_FRG BOOLEAN Operate signal for frequency gradient

START BOOLEAN Start

ST_OFRQ BOOLEAN Start signal for overfrequency

ST_UFRQ BOOLEAN Start signal for underfrequency

ST_FRG BOOLEAN Start signal for frequency gradient

4.6.1.7 Settings

Table 391: FRPFRQ Group settings

Parameter Values (Range) Unit Step Default DescriptionOperation mode 1=Freq<

2=Freq>3=df/dt4=Freq< + df/dt5=Freq> + df/dt6=Freq< OR df/dt7=Freq> OR df/dt

1=Freq< Frequency protection operation modeselection

Start value Freq> 0.9000...1.2000 xFn 0.0001 1.0500 Frequency start value overfrequency

Start value Freq< 0.8000...1.1000 xFn 0.0001 0.9500 Frequency start value underfrequency

Start value df/dt -0.200...0.200 xFn /s 0.005 0.010 Frequency start value rate of change

Operate Tm Freq 80...200000 ms 10 200 Operate delay time for frequency

Operate Tm df/dt 120...200000 ms 10 400 Operate delay time for frequency rate ofchange

Table 392: FRPFRQ Non group settings



Reset delay Tm Freq 0...60000 ms 1 0 Reset delay time for frequency

Reset delay Tm df/dt 0...60000 ms 1 0 Reset delay time for rate of change




Table 393: FRPFRQ Monitored data

Name Type Values (Range) Unit DescriptionSTART_DUR FLOAT32 0.00...100.00 % Start duration

ST_DUR_OFRQ FLOAT32 0.00...100.00 % Start duration

ST_DUR_UFRQ FLOAT32 0.00...100.00 % Start duration

ST_DUR_FRG FLOAT32 0.00...100.00 % Start duration

FRPFRQ Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 394: FRPFRQ Technical data

Characteristic ValueOperation accuracy f>/f< ±10 mHz

df/dt ±100 mHz/s (in range |df/dt| < 5Hz/s)± 2.0% of the set value (inrange 5 Hz/s < |df/dt| < 15 Hz/s)

Start time f>/f< < 80 ms

df/dt < 120 ms

Reset time < 150 ms


4.6.2 Load shedding and restoration LSHDPFRQ





Load shedding and restoration LSHDPFRQ UFLS/R 81LSH




GUID-1B46D13E-4F26-4CFA-9655-E979E0E05D67 V2 EN



The load shedding and restoration function LSHDPFRQ is capable of performingload shedding based on underfrequency and the rate of change of the frequency.The load that is shed during the frequency disturbance can be restored once thefrequency has stabilized to the normal level.

The measured system frequency is compared to the set value to detect theunderfrequency condition. The measured rate of change of frequency (df/dt) iscompared to the set value to detect a high frequency reduction rate. Thecombination of the detected underfrequency and the high df/dt is used for theactivation of the load shedding. There is a definite time delay between the detectionof the underfrequency and high df/dt and the activation of LSHDPFRQ. This timedelay can be set and it is used to prevent unwanted load-shedding actions when thesystem frequency recovers to the normal level.

Throughout this document, “high df/dt” is used to mean “a high rateof change of the frequency in negative direction.”

Once the frequency has stabilized, LSHDPFRQ can restore the load that is shedduring the frequency disturbance. The restoration is possible manually orautomatically.




The operation of the load shedding and restoration function can be described usinga module diagram. All the modules are explained in the next sections.



GUID-17F7A604-487F-4D45-8150-AE041BB939B1 V2 EN


Underfrequency detectionThe underfrequency detection measures the input frequency calculated from thevoltage signal. An underfrequency is detected when the measured frequency dropsbelow the set value of the Start Value Freq setting.

The underfrequency detection module includes a timer with the definite time (DT)characteristics. Upon detection of underfrequency, operation timer activates theST_FRQ output. When the underfrequency timer has reached the value set byOperate Tm Freq, the OPR_FRQ output is activated if the underfrequencycondition still persists. If the frequency becomes normal before the moduleoperates, the reset timer is activated. If the reset timer reaches the value set byReset delay time, the timer resets and the ST_FRQ output is deactivated.

df/dt detectionThe df/dt detection measures the input frequency calculated from the voltage signaland calculates its gradient. A high df/dt condition is detected by comparing the



gradient to the Start value df/dt setting.The df/dt detection is activated when thefrequency gradient decreases at a faster rate than the set value of Start value df/dt.

The df/dt detection module includes a timer with the DT characteristics. Upondetection of df/dt, operation timer activates the ST_FRG output. When the timerhas reached the value set by Operate Tm df/dt, the OPR_FRG output is activated ifthe df/dt condition still persists. If df/dt becomes normal before the moduleoperates, the reset timer is activated. If the reset timer reaches the value of theReset delay time setting, the timer resets and the ST_FRG output is deactivated.

Load-shedding controlThe way of load shedding, that is, whether to operate based on underfrequency orhigh df/dt or both, is defined with the Load shed mode user setting. The validoperation modes for the Load shed mode settings are "Freq<", "Freq< AND df/dt"and "Freq< OR df/dt".

Once the selected operation mode conditions are satisfied, the START andOPERATE output signals are activated.

When the START output is active, the percentage of the elapsed delay time can bemonitored through START_DUR which is available as monitored data.



50 Hz

Start value Freq set at 0.975 xFnStart value df/dt set at -0.020 xFn/sOperate Tm df/dt = 500msOperate Tm Freq = 1000msLoad shed mode = Freq< AND df/dt 49 Hz

ST_FRG

OPR_FRG

500ms

1s

OPERATE is activated as Freq< AND df/dt condition satisfiedOPERATE

48.75 Hz

Start of operation timer

ST_FRQ

OPR_FRQ


1s

Time [s]

Frequency[Hz]

GUID-143A36EB-FCC9-4E87-B615-7743A3D75A15 V2 EN

Figure 235: Load-shedding operation in the “Freq< AND df/dt>” mode whenboth Freq< and df/dt conditions are satisfied (Rated frequency=50Hz)



50 Hz

Start value Freq set at 0.975 xFnStart value df/dt set at -0.020 xFn/sOperate Tm df/dt = 500msOperate Tm Freq = 1000msLoad shed mode = Freq< AND df/dt

49 Hz

ST_FRG

OPR_FRG

500ms

1s

OPERATE is not activated in this case

as Freq< condition not satisfied

OPERATE


Time [s]

Frequency[Hz]

GUID-DB333B09-D987-4A62-ABAE-7B70ACA275EB V2 EN

Figure 236: Load-shedding operation in the “Freq< AND df/dt>” mode whenonly the df/dt condition is satisfied (Rated frequency=50 Hz)

Restore detectionIf after the activation of the OPERATE input the frequency recovers to a levelabove the Restore start Val setting, the RESTORE signal output is activated. TheRESTORE output remains active for a 100 ms. The Restore mode setting is used toselect the restoring mode to be "Disabled", "Auto" or "Manual".



Restoring mode DescriptionDisabled Load restoration is disabled.

Auto In the “Auto” mode, input frequency is continuously compared to the Restorestart Val setting. The restore detection module includes a timer with the DTcharacteristics. Upon detection of restoring, the operation timer activates theST_REST output. When the timer has reached the value of the Restore delaytime setting, the RESTORE output is activated if the restoring condition stillpersists. If the frequency drops below the Restore start Val before theRESTORE output is activated, the reset timer is activated. If the reset timerreaches the value of the Reset delay time setting, the timer resets and theST_REST start output is deactivated.

Manual In the “Manual” mode, a manual restoration is possible through theMAN_RESTORE input or via communication. The ST_REST output is activatedif the MAN_RESTORE command is available and the frequency has exceededthe Restore start Val setting. The manual restoration includes a timer withthe DT characteristics. When the timer has reached the set value of theRestore delay time setting, the RESTORE output is activated if the restoringcondition still persists. If the frequency drops below the Restore start Valsetting before the RESTORE output is activated, the reset timer is activated. Ifthe reset timer reaches the value of the Reset delay time setting, the timerresets and the ST_REST start output is deactivated.

A condition can arise where the restoring operation needs to be canceled.Activating the BLK_REST input for the "Auto" or "Manual" modes cancels therestoring operation. In the "Manual" restoring mode, the cancellation happens evenif MAN_RESTORE is present.

Once the RESTORE output command is cancelled, the reactivation of RESTORE ispossible only after the reactivation of the OPERATE output, that is, when the nextload-shedding operation is detected.

Blocking logicThere are three operation modes in the blocking functionality. The operation modesare controlled by the BLOCK input and the Configuration/System/Blocking modeglobal setting that selects the blocking mode. The BLOCK input can be controlledwith a binary input, a horizontal communication input or an internal signal of theIED program. The influence of the BLOCK input signal activation is preselectedwith the Blocking mode global setting.

The Blocking mode setting has three blocking methods. In the "Freeze timers"mode, the operate timer is frozen to the prevailing value. In the "Block all" mode,the whole function is blocked and the timers are reset. In the "Block OPERATEoutput" mode, the function operates normally but the OPERATE, OPR_FRQ andOPR_FRG outputs are not activated.

4.6.2.5 Application

An AC power system operates at a defined rated frequency. The nominal frequencyin most systems in the world is 50 Hz or 60 Hz. The system operation is such thatthe operating frequency remains approximately at the nominal frequency value by



a small margin. The safe margin of operation is usually less than ±0.5 Hz. Thesystem frequency stability is one of the main concerns in the transmission anddistribution network operation and control. To protect the frequency-sensitiveelectrical equipment in the network, departure from the allowed band for safeoperation should be inhibited.

Any increase in the connected load requires an increase in the real powergeneration to maintain the system frequency. Frequency variations form wheneverthere are system conditions that result in an unbalance between the generation andload. The rate of change of the frequency represents the magnitude of thedifference between the load and generation. A reduction in frequency and anegative rate of change of the frequency are observed when the load is greater thanthe generation, and an increase in the frequency along with a positive rate ofchange of the frequency are observed if the generation is greater than the load. Therate of change of the frequency is used for a faster decision of load shedding. In anunderfrequency situation, the load shedding trips out the unimportant loads tostabilize the network. Thus, loads are normally prioritized so that the less importantloads are shed before the important loads.

During the operation of some of the protective schemes or other systememergencies, the power system is divided into small islands. There is always a load- generation imbalance in such islands that leads to a deviation in the operatingfrequency from the nominal frequency. This off-nominal frequency operation isharmful to power system components like turbines and motors. Therefore, suchsituation must be prevented from continuing. The frequency-based load-sheddingscheme should be applied to restore the operation of the system to normalfrequency. This is achieved by quickly creating the load - generation balance bydisconnecting the load.

As the formation of the system islands is not always predefined, several load-shedding relays are required to be deployed at various places near the load centers.A quick shedding of a large amount of load from one place can cause a significantdisturbance in the system. The load-shedding scheme can be made most effective ifthe shedding of load feeders is distributed and discrete, that is, the loads are shed atvarious locations and in distinct steps until the system frequency reaches theacceptable limits.

Due to the action of load-shedding schemes, the system recovers from thedisturbance and the operating frequency value recovers towards the nominalfrequency. The load that was shed during the disturbance can be restored. The load-restoring operation should be done stepwise in such a way that it does not lead thesystem back to the emergency condition. This is done through an operatorintervention or in case of remote location through an automatic load restorationfunction. The load restoration function also detects the system frequency andrestores the load if the system frequency remains above the value of the setrestoration frequency for a predefined duration.



ST_REST

50 Hz

Frequency [Hz]

48.8 Hz

START

OPERATE

Time [s]

RESTORE

Set Restore delay time

Restoretimer

Timer starts

Timer continues

Timer suspended

GUID-8694ACBB-CC73-46E6-A9C9-5DE27F6FC7AF V3 EN

Figure 237: Operation of the load-shedding function

Power system protection by load sheddingThe decision on the amount of load that is required to be shed is taken through themeasurement of frequency and the rate of change of frequency (df/dt). At a singlelocation, many steps of load shedding can be defined based on different criteria ofthe frequency and df/dt. Typically, the load shedding is performed in six or foursteps with each shedding increasing the portion of load from five to twenty-fivepercent of full load within a few seconds. After every shedding, the systemfrequency is read back and further shedding actions are taken only if necessary. Inorder to take the effect of any transient, a sufficient time delay should be set.

The value of the setting has to be well below the lowest occurring normalfrequency and well above the lowest acceptable frequency of the system. Thesetting level, the number of steps and the distance between two steps (in time or infrequency) depend on the characteristics of the power system under consideration.The size of the largest loss of generation compared to the size of the power systemis a critical parameter. In large systems, the load shedding can be set at a highfrequency level and the time delay is normally not critical. In small systems, thefrequency start level has to be set at a low value and the time delay must be short.



If a moderate system operates at 50 Hz, an underfrequency should be set fordifferent steps from 49.2 Hz to 47.5 Hz in steps of 0.3 – 0.4 Hz. The operating timefor the underfrequency can be set from a few seconds to a few fractions of a secondstepwise from a higher frequency value to a lower frequency value.

Table 395: Setting for a five-step underfrequency operation

Load-shedding steps Start value Freq setting Operate Tm Freq setting1 0.984 · Fn (49.2 Hz) 45000 ms

2 0.978 · Fn (49.2 Hz) 30000 ms

3 0.968 · Fn (49.2 Hz) 15000 ms

4 0.958 · Fn (49.2 Hz) 5000ms

5 0.950 · Fn (49.2 Hz) 500 ms

The rate of change of frequency function is not instantaneous since the functionneeds time to supply a stable value. It is recommended to have a time delay longenough to take care of the signal noise.

Small industrial systems can experience the rate of change of frequency as large as5 Hz/s due to a single event. Even large power systems can form small islands witha large imbalance between the load and generation when severe faults orcombinations of faults are cleared. Up to 3 Hz/s has been experienced when a smallisland becomes isolated from a large system. For normal severe disturbances inlarge power systems, the rate of change of the frequency is much less, often just afraction of 1.0 Hz/s.

Similarly, the setting for df/dt can be from 0.1 Hz/s to 1.2 Hz/s in steps of 0.1 Hz/sto 0.3 Hz/s for large distributed power networks, with the operating time varyingfrom a few seconds to a few fractions of a second. Here, the operating time shouldbe kept in minimum for the higher df/dt setting.

Table 396: Setting for a five-step df/dt< operation

Load-shedding steps Start value df/dt setting Operate Tm df/dt setting1 -0.005 · Fn /s (-0.25 Hz/s) 8000 ms

2 -0.010 · Fn /s (-0.25 Hz/s) 2000 ms

3 -0.015 · Fn /s (-0.25 Hz/s) 1000 ms

4 -0.020 · Fn /s (-0.25 Hz/s) 500 ms

5 -0.025 · Fn /s (-0.25 Hz/s) 250 ms

Once the frequency has stabilized, the shed load can be restored. The restoringoperation should be done stepwise, taking care that it does not lead the system backto the emergency condition.



Table 397: Setting for a five-step restoring operation

Load-shedding steps Restoring start Val setting Restore delay time setting1 0.990 · Fn (49.5 Hz) 200000 ms

2 0.990 · Fn (49.5 Hz) 160000 ms

3 0.990 · Fn (49.5 Hz) 100000 ms

4 0.990 · Fn (49.5 Hz) 50000 ms

5 0.990 · Fn (49.5 Hz) 10000 ms

4.6.2.6 Signals

Table 398: LSHDPFRQ Input signals

Name Type Default DescriptionF SIGNAL 0 Measured frequency

dF/dt SIGNAL 0 Rate of change of frequency


BLK_REST BOOLEAN 0=False Block restore

MAN_RESTORE BOOLEAN 0=False Manual restore signal

Table 399: LSHDPFRQ Output signals

Name Type DescriptionOPERATE BOOLEAN Operation of load shedding

OPR_FRQ BOOLEAN Operate signal for under frequency

OPR_FRG BOOLEAN Operate signal for high df/dt

START BOOLEAN Start

ST_FRQ BOOLEAN Pick-Up signal for under frequency detection

ST_FRG BOOLEAN Pick-Up signal for high df/dt detection

RESTORE BOOLEAN Restore signal for load restoring purposes

ST_REST BOOLEAN Restore frequency attained and restore timerstarted

4.6.2.7 Settings

Table 400: LSHDPFRQ Group settings

Parameter Values (Range) Unit Step Default DescriptionLoad shed mode 1=Freq<

6=Freq< OR df/dt8=Freq< AND df/dt

1=Freq< Set the operation mode for loadshedding function

Restore mode 1=Disabled2=Auto3=Manual

1=Disabled Mode of operation of restore functionality

Start value Freq 0.800...1.200 xFn 0.001 0.975 Frequency setting/start value




Parameter Values (Range) Unit Step Default DescriptionStart value df/dt -0.200...-0.005 xFn /s 0.005 -0.010 Setting of frequency gradient for df/dt

detection

Operate Tm Freq 80...200000 ms 10 200 Time delay to operate for underfrequency stage

Operate Tm df/dt 120...200000 ms 10 200 Time delay to operate for df/dt stage

Restore start Val 0.800...1.200 xFn 0.001 0.998 Restore frequency setting value

Restore delay time 80...200000 ms 10 300 Time delay to restore

Table 401: LSHDPFRQ Non group settings



Reset delay time 0...60000 ms 1 50 Time delay after which the definite timerswill reset


Table 402: LSHDPFRQ Monitored data

Name Type Values (Range) Unit DescriptionSTART_DUR FLOAT32 0.00...100.00 % Start duration

LSHDPFRQ Enum 1=on2=blocked3=test4=test/blocked5=off

Status


Table 403: LSHDPFRQ Technical data

Characteristic ValueOperation accuracy f< ±10 mHz

df/dt ±100 mHz/s (in range |df/dt| < 5Hz/s)± 2.0% of the set value (inrange 5 Hz/s < |df/dt| < 15 Hz/s)

Start time f< < 80 ms

df/dt < 120 ms

Reset time < 150 ms




4.7 Arc protection ARCSARC

4.7.1 IdentificationFunction description IEC 61850

identificationIEC 60617identification


Arc protection ARCSARC ARC 50L/50NL


A070686 V3 EN


4.7.3 FunctionalityThe arc protection ARCSARC detects arc situations in air insulated metal-cladswitchgears caused by, for example, human errors during maintenance or insulationbreakdown during operation.

The function detects light from an arc either locally or via a remote light signal.The function also monitors phase and residual currents to be able to make accuratedecisions on ongoing arcing situations.

The function contains a blocking functionality. Blocking deactivates all outputsand resets timers.

4.7.4 Operation principleThe function can be enabled and disabled with the Operation setting. Thecorresponding parameter values are "On" and "Off".

The operation of arc protection can be described by using a module diagram. Allthe modules in the diagram are explained in the next sections.



OPERATE

Leveldetector

1

I_AI_BI_C

BLOCK

Leveldetector

2Io

FLT_ARCREM_FLT_ARC

ARC_FLT_DET

Operation mode

selector t

Dropoff

OPR_MODE

t

Dropoff

A070746 V4 EN


Level detector 1The measured phase currents are compared phasewise to the set Phase start value.If the measured value exceeds the set Phase start value, the level detector reportsthe exceeding of the value to the operation mode selector.

Level detector 2The measured residual currents are compared to the set Ground start value. If themeasured value exceeds the set Ground start value, the level detector reports theexceeding of the value to the operation mode selector.

Operation mode selectorDepending on the Operation mode setting, the operation mode selector makes surethat all required criteria are fulfilled for a reliable decision of an arc fault situation.The user can select either "Light+current", "Light only" or "BI controlled"operation mode. The operation is based on both current and light information in “Light+current” mode, on light information only in “Light only” mode or on remotelycontrolled information in “BI controlled” mode. When the "BI controlled" mode isin use and the OPR_MODE input is activated, the operation of the function is basedon light information only. When the OPR_MODE input is deactivated, the operationof the function is based on both light and current information. When the requiredcriteria are met, the drop-off timer is activated.

Drop-off timerOnce activated, the drop-off timer remains active until the input is deactivated or atleast during the drop-off time. The BLOCK signal can be used to block theOPERATE signal or the light signal output ARC_FLT_DET.



4.7.5 ApplicationThe arc protection can be realized as a stand-alone function in a single relay or as astation-wide arc protection, including several protection relays. If realized as astation-wide arc protection, different tripping schemes can be selected for theoperation of the circuit breakers of the incoming and outgoing feeders.Consequently, the relays in the station can, for example, be set to trip the circuitbreaker of either the incoming or the outgoing feeder, depending on the faultlocation in the switchgear. For maximum safety, the relays can be set to always tripboth the circuit breaker of the incoming feeder and that of the outgoing feeder.

The arc protection consists of:

• Optional arc light detection hardware with automatic backlight compensationfor lens type sensors

• Light signal output ARC_FLT_DET for routing indication of locally detectedlight signal to another relay

• Protection stage with phase- and earth-fault current measurement.

The function detects light from an arc either locally or via a remote light signal.Locally, the light is detected by lens sensors connected to the inputs Light sensor 1,Light sensor 2, or Light sensor 3 on the serial communication module of the relay.The lens sensors can be placed, for example, in the busbar compartment, thebreaker compartment, and the cable compartment of the metal-clad cubicle.

The light detected by the lens sensors is compared to an automatically adjustedreference level. Light sensor 1, Light sensor 2, and Light sensor 3 inputs have theirown reference levels. When the light exceeds the reference level of one of theinputs, the light is detected locally. When the light has been detected locally orremotely and, depending on the operation mode, if one or several phase currentsexceed the set Phase start value limit, or the earth-fault current the set Groundstart value limit, the arc protection stage generates an operation signal. The stage isreset in 30 ms, after all three-phase currents and the earth-fault current have fallenbelow the set current limits.

The light signal output from an arc protection stage ARC_FLT_DET is activatedimmediately in the detection of light in all situations. A station-wide arc protectionis realized by routing the light signal output to an output contact connected to abinary input of another relay, or by routing the light signal output through thecommunication to an input of another relay.

It is possible to block the tripping and the light signal output of the arc protectionstage with a binary input or a signal from another function block.

Cover unused inputs with dust caps.



Arc protection with one IEDIn installations, with limited possibilities to realize signalling between IEDsprotecting incoming and outgoing feeders, or if only the IED for the incomingfeeder is to be exchanged, an arc protection with a lower protective level can beachieved with one protection relay. An arc protection with one IED only is realizedby installing two arc lens sensors connected to the IED protecting the incomingfeeder to detect an arc on the busbar. In arc detection, the arc protection stage tripsthe circuit breaker of the incoming feeder. The maximum recommendedinstallation distance between the two lens sensors in the busbar area is six metersand the maximum distance from a lens sensor to the end of the busbar is three meters.

A040362 V1 EN

Figure 240: Arc protection with one IED

Arc protection with several IEDsWhen using several IEDs, the IED protecting the outgoing feeder trips the circuitbreaker of the outgoing feeder when detecting an arc at the cable terminations. Ifthe IED protecting the outgoing feeder detects an arc on the busbar or in thebreaker compartment via one of the other lens sensors, it will generate a signal tothe IED protecting the incoming feeder. When detecting the signal, the IEDprotecting the incoming feeder trips the circuit breaker of the incoming feeder andgenerates an external trip signal to all IEDs protecting the outgoing feeders, whichin turn results in tripping of all circuit breakers of the outgoing feeders. For



maximum safety, the IEDs can be configured to trip all the circuit breakersregardless of where the arc is detected.

Q1

Q2

M1

Q3 Q4 Q5 Q6

PO3

PO1

3I, Io

S1 S2 S3 S4

DI1

SO1SO1SO1

DI1 DI1 DI13I, Io3I, Io 3I, Io3I, Io

DI1

SO1

SO1

A040363 V3 EN

Figure 241: Arc protection with several IEDs

Arc protection with several IEDs and a separate arc protection systemWhen realizing an arc protection with both IEDs and a separate arc protectionsystem, the cable terminations of the outgoing feeders are protected by IEDs usingone lens sensor for each IED. The busbar and the incoming feeder are protected bythe sensor loop of the separate arc protection system. With arc detection at thecable terminations, an IED trips the circuit breaker of the outgoing feeder.However, when detecting an arc on the busbar, the separate arc protection systemtrips the circuit breaker of the incoming feeder and generates an external trip signalto all IEDs protecting the outgoing feeders, which in turn results in tripping of allcircuit breakers of the outgoing feeders.



A040364 V1 EN

Figure 242: Arc protection with several IEDs and a separate arc protectionsystem

4.7.6 SignalsTable 404: ARCSARC Input signals





BLOCK BOOLEAN 0=False Block signal for all binary outputs

REM_FLT_ARC BOOLEAN 0=False Remote Fault arc detected

OPR_MODE BOOLEAN 0=False Operation mode input

Table 405: ARCSARC Output signals


ARC_FLT_DET BOOLEAN Fault arc detected=light signal output



4.7.7 SettingsTable 406: ARCSARC Group settings

Parameter Values (Range) Unit Step Default DescriptionPhase start value 0.50...40.00 xIn 0.01 2.50 Operating phase current

Ground start value 0.05...8.00 xIn 0.01 0.20 Operating residual current

Operation mode 1=Light+current2=Light only3=BI controlled

1=Light+current Operation mode

Table 407: ARCSARC Non group settings



4.7.8 Monitored dataTable 408: ARCSARC Monitored data

Name Type Values (Range) Unit DescriptionARCSARC Enum 1=on

2=blocked3=test4=test/blocked5=off

Status

4.7.9 Technical dataTable 409: ARCSARC Technical data

Characteristic ValueOperation accuracy ±3% of the set value or ±0.01 x In

Operate time Minimum Typical Maximum

Operation mode ="Light+current"1)2)

9 ms 12 ms 15 ms

Operation mode ="Light only"2)

9 ms 10 ms 12 ms

Reset time < 40 ms


1) Phase start value = 1.0 x In, current before fault = 2.0 x set Phase start value, fn = 50 Hz, fault withnominal frequency, results based on statistical distribution of 200 measurements

2) Includes the delay of the heavy-duty output contact



4.8 Motor startup supervision STTPMSU




Motor startup supervision STTPMSU Is2tn< 49,66,48,51LR


GUID-A37CF63B-5273-423B-9DC3-AACADB668AEE V1 EN


4.8.3 FunctionalityThe motor startup supervision function STTPMSU is designed for protectionagainst excessive starting time and locked rotor conditions of the motor duringstarting. For a good and reliable operation of the motor, the thermal stress duringthe motor starting is maintained within the allowed limits.

The starting of the motor is supervised by monitoring the TRMS magnitude of allthe phase currents or by monitoring the status of the circuit breaker connected tothe motor.

During the startup period of the motor, STTPMSU calculates the integral of the I²tvalue. If the calculated value exceeds the set value, the operate signal is activated.

STTPMSU has the provision to check the locked rotor condition of the motor usingthe speed switch, which means checking if the rotor is able to rotate or not. Thisfeature operates after a predefined operating time.

STTPMSU also protects the motor from an excessive number of startups. Uponexceeding the specified number of startups within certain duration, STTPMSUblocks further starts. The restart of the motor is also inhibited after each start andcontinues to be inhibited for a set duration. When the lock of start of motor isenabled, STTPMSU gives the time remaining until the restart of the motor.

STTPMSU contains a blocking functionality. It is possible to block functionoutputs, timer or the function itself, if desired.




The operation of the motor startup supervision function can be described with amodule diagram. All the modules in the diagram are explained in the next sections.

GUID-35DD1223-14B2-48BF-ADF4-4A1DF6930314 V1 EN


Startup supervisorThis module detects the starting of the motor. The starting and stalling motorconditions are detected in four different modes of operation. This is done throughthe Operation mode setting.

When the Operation mode setting is operated in the "IIt" mode, the functioncalculates the value of the thermal stress of the motor during the startup condition.In this mode, the startup condition is detected by monitoring the TRMS currents.

The Operation mode setting in the "IIt, CB" mode enables the function to calculatethe value of the thermal stress when a startup is monitored in addition to theCB_CLOSED input.

In the "IIt & stall" mode, the function calculates the thermal stress of the motorduring the startup condition. The startup condition is detected by monitoring theTRMS currents.

In the "IIt & stall, CB" mode, the function calculates the thermal stress of themotor during the startup condition but the startup condition is detected bymonitoring the TRMS current as well as circuit breaker status.

In both the "IIt & stall" and "IIt & stall, CB" mode, the function also checks formotor stalling by monitoring the speed switch.



When the measured current value is used for startup supervision in the "IIt" and "IIt& stall" modes, the module initially recognizes the de-energized condition of themotor when the values of all three phase currents are less than Motor standstill Afor longer than 100 milliseconds. If any of the phase currents of the de-energizedcondition rises to a value equal to or greater than Motor standstill A, theMOT_START output signal is activated indicating that the motor startup is inprogress. The MOT_START output remains active until the values of all three phasecurrents drop below 90 percent of the set value of Start detection A and remainbelow that level for a time of Str over delay time, that is, until the startup situationis over.

GUID-4475BDFB-57AE-4BFD-9EE7-AE7672F7206E V2 EN

Figure 245: Functionality of startup supervision in the "IIt and IIt&stall" mode

In case of the "IIt, CB" or "IIt & stall, CB" modes, the function initially recognizesthe de-energized condition of the motor when the value of all three phase currentsis below the value of the Motor standstill A setting for 100 milliseconds. Thebeginning of the motor startup is recognized when CB is closed, that is, when theCB_CLOSED input is activated and at least one phase current value exceeds theMotor standstill A setting.

These two events do not take place at the same instant, that is, the CB main contactis closed first, in which case the phase current value rises above 0.1 pu and aftersome delay the CB auxiliary contact gives the information of the CB_CLOSEDinput. In some cases, the CB_CLOSED input can be active but the value of currentmay not be greater than the value of the Motor standstill A setting. To allow bothpossibilities, a time slot of 200 milliseconds is provided for current and theCB_CLOSED input. If both events occur during this time, the motor startup isrecognized.

The motor startup ends either within the value of the Str over delay time settingfrom the beginning of the startup or the opening of CB or when the CB_CLOSED



input is deactivated. The operation of the MOT_START output signal in thisoperation mode is as illustrated in Figure 246.

This CB mode can be used in soft-started or slip ring motors for protection againsta large starting current, that is, a problem in starting and so on.

GUID-DDAD7B3F-28BE-4573-BE79-FBB488A22ECA V1 EN

GUID-1470A4DB-310F-46BC-B775-843EAB8BA836 V1 EN

Figure 246: Functionality of startup supervision in the "IIt, CB" mode and the "IItand stall, CB" mode

The Str over delay time setting has different purposes in different modes of operation.

• In the “IIt” or “IIt & stall” modes, the aim of this setting is to check for thecompletion of the motor startup period. The purpose of this time delay settingis to allow for short interruptions in the current without changing the state of



the MOT_START output. In this mode of operation, the value of the setting isin the range of around 100 milliseconds.

• In the “IIt, CB” or “IIt & stall, CB” modes, the purpose of this setting is tocheck for the life of the protection scheme after the CB_CLOSED input hasbeen activated. Based on the values of the phase currents, the completion ofthe startup period cannot be judged. So in this mode of operation, the value ofthe time delay setting can even be as high as within the range of seconds, forexample around 30 seconds.

The activation of the BLOCK input signal deactivates the MOT_START output.

Thermal stress calculatorBecause of the high current surges during the startup period, a thermal stress isimposed on the rotor. With less air circulation in the ventilation of the rotor beforeit reaches its full speed, the situation becomes even worse. Consequently, a longstartup causes a rapid heating of the rotor.

This module calculates the thermal stress developed in the motor during startup.The heat developed during the starting can be calculated with the formula.

W R i t dts s

t

= ( )∫2

0

GUID-7A92209F-7451-415B-8C3D-276A6ED4A44B V1 EN (Equation 60)

Rs combined rotor and stator resistance

is starting current of the motor

t starting time of the motor

This equation is normally represented as the integral of I²t. It is a commonly usedmethod in protective IEDs to protect the motor from thermal stress during starting.The advantage of this method over the traditional definite time overcurrentprotection is that when the motor is started with a reduced voltage as in the star-delta starting method, the starting current is lower. This allows more starting timefor the motor since the module is monitoring the integral of I²t.

The module calculates the accumulated heat continuously and compares it to thelimiting value obtained from the product of the square of the values of the Motorstart-up A and Motor start-up time settings. When the calculated value of thethermal stress exceeds this limit, the OPR_IIT output is activated.

The module also measures the time START_TIME required by the motor to attainthe rated speed and the relative thermal stress IIT_RL. The values are available inthe monitored data view.

The activation of the BLOCK input signal resets the thermal stress calculator anddeactivates the OPR_IIT output.



Stall protectionThis module is activated only when the selected Operation mode setting value is"IIt & stall" or "IIt & stall, CB".

The startup current is specific to each motor and depends on the startup methodused, such as direct online, autotransformer and rotor resistance insertion. Thestartup time is dependent of the load connected to the motor.

Based on the motor characteristics supplied by the manufacturer, this module isrequired if the stalling time is shorter than or too close to the starting time. In suchcases, a speed switch must be used to indicate whether a motor is acceleratingduring startup or not.

At motor standstill, the STALL_IND input is active. It indicates that the rotor isnot rotating. When the motor is started, at certain revolution the deactivation of theSTALL_IND by the speed switch indicates that the rotor is rotating. If the input isnot deactivated within Lock rotor time, the OPR_STALL output is activated.

The module calculates the duration of the motor in stalling condition, theSTALL_RL output indicating the percent ratio of the start situation and the setvalue of Lock rotor time. The value is available in the monitored data view.

The activation of the BLOCK input signal resets the operation time and deactivatesthe OPR_STALL output.

Cumulative startup protectionThis module protects the motor from an excessive number of startups.

Whenever the motor is started, the latest value of START_TIME is added to theexisting value of T_ST_CNT and the updated cumulative startup time is availableat T_ST_CNT. If the value of T_ST_CNT is greater than the value of Cumulativetime Lim, the LOCK_START output is activated and motor restarting is inhibitedduring the time the output is active. The LOCK_START output remains high untilthe T_ST_CNT value reduces to a value less than the value of Cumulative timeLim. The start time counter reduces at the rate of the value of Counter Red rate.

The LOCK_START output becomes activated at the start of MOT_START. Theoutput remains active for a period of Restart inhibit time.



GUID-200BC4CB-8B33-4616-B014-AFCC99ED9224 V2 EN

Figure 247: Time delay for cumulative start

This module also protects the motor from consecutive startups. When theLOCK_START output is active, T_RST_ENA shows the possible time for nextrestart. The value of T_RST_ENA is calculated by the difference of Restart inhibittime and the elapsed time from the instant LOCK_START is enabled.

When the ST_EMERG_ENA emergency start is set high, the value of thecumulative startup time counter is set to Cumulative time Lim - 60s × Emg startRed rate. This disables LOCK_START and in turn makes the restart of the motorpossible.

This module also calculates the total number of startups occurred, START_CNT.The value can be reset from the clear menu.

The calculated values of T_RST_ENA, T_ST_CNT and START_CNT are availablein the monitored data view.

The activation of the BLK_LK_ST input signal deactivates the LOCK_STARToutput. The activation of the BLOCK input signal resets the cumulative startupcounter module.

4.8.5 ApplicationWhen a motor is started, it draws a current well in excess of the motor's full-loadrating throughout the period it takes for the motor to run up to the rated speed. Themotor starting current decreases as the motor speed increases and the value ofcurrent remains close to the rotor-locked value for most of the acceleration period.

The full-voltage starting or the direct-on-line starting method is used out of themany methods used for starting the induction motor. If there is either an electricalor mechanical constraint, this starting method is not suitable. The full-voltage



starting produces the highest starting torque. A high starting torque is generallyrequired to start a high-inertia load to limit the acceleration time. In this method,full voltage is applied to the motor when the switch is in the "On" position. Thismethod of starting results in a large initial current surge, which is typically four toeight times that of the full-load current drawn by the motor. If a star-delta starter isused, the value of the line current will only be about one-third of the direct-on-linestarting current.

GUID-F4C17D13-48CA-480A-BBE5-DFD7D6316DB8 V1 EN

Figure 248: Typical motor starting and capability curves

The startup supervision of a motor is an important function because of the higherthermal stress developed during starting. During the startup, the current surgeimposes a thermal strain on the rotor. This is exaggerated as the air flow forcooling is less because the fans do not rotate in their full speed. Moreover, thedifference of speed between the rotating magnetic field and the rotor during thestartup time induces a high magnitude of slip current in the rotor at frequencieshigher than when the motor is at full speed. The skin effect is stronger at higherfrequencies and all these factors increase the losses and the generated heat. This isworse when the rotor is locked.

The starting current for slip-ring motors is less than the full load current andtherefore it is advisable to use the circuit breaker in the closed position to indicatethe starting for such type of motors.

The starting times vary depending on motor design and load torque characteristics.The time taken may vary from less than two seconds to more than 60 seconds. Thestarting time is determined for each application.

When the permissible stall time is less than the starting time of the motor, thestalling protection is used and the value of the time delay setting should be setslightly less than the permissible stall time. The speed switch on the motor shaft



must be used for detecting whether the motor begins to accelerate or not. However,if the safe stall time is longer than the startup time of the motor, the speed switch isnot required.

The failure of a motor to accelerate or to reach its full nominal speed in anacceptable time when the stator is energized is caused by several types of abnormalconditions, including a mechanical failure of the motor or load bearings, lowsupply voltage, open circuit in one phase of a three-phase voltage supply or toohigh starting voltage. All these abnormal conditions result in overheating.

Repeated starts increase the temperature to a high value in the stator or rotorwindings, or both, unless enough time is allowed for the heat to dissipate. Toensure a safe operation it is necessary to provide a fixed-time interval betweenstarts or limit the number of starts within a period of time. This is why the motormanufacturers have restrictions on how many starts are allowed in a defined timeinterval. This function does not allow starting of the motor if the number of startsexceeds the set level in the register that calculates them. This insures that thethermal effects on the motor for consecutive starts stay within permissible levels.

For example, the motor manufacturer may state that three starts at the maximumare allowed within 4 hours and the startup situation time is 60 seconds. Byinitiating three successive starts we reach the situation as illustrated. As a result,the value of the register adds up to a total of 180 seconds. Right after the third starthas been initiated, the output lock of start of motor is activated and the fourth startwill not be allowed, provided the time limit has been set to 121 seconds.

Furthermore, a maximum of three starts in 4 hours means that the value of theregister should reach the set start time counter limit within 4 hours to allow a newstart. Accordingly, the start time counter reduction should be 60 seconds in 4 hoursand should thus be set to 60 s / 4 h = 15 s / h.

GUID-6E9B7247-9009-4302-A79B-B326009ECC7A V2 EN

Figure 249: Typical motor-starting and capability curves



Setting of Cumulative time Lim

Cumulative time Lim is calculated by

t n t marginsi∑ = − × +( )1

GUID-0214B677-48D0-4DD4-BD1E-67BA9FD3C345 V1 EN (Equation 61)

n specified maximum allowed number of motor startups

t startup time of the motor (in seconds)

margin safety margin (~10...20 percent)

Setting of Counter Red rate

Counter Red rate is calculated by

∆ tt

ts

reset

∑ =

GUID-E7C44256-0F67-4D70-9B54-1C5042A151AF V1 EN (Equation 62)

t specified start time of the motor in seconds

treset duration during which the maximum number of motor startups stated by the manufacturer canbe made; time in hours

4.8.6 SignalsTable 410: STTPMSU Input signals




BLOCK BOOLEAN 0=False Block of function

BLK_LK_ST BOOLEAN 0=False Blocks lock out condition for restart of motor

CB_CLOSED BOOLEAN 0=False Input showing the status of motor circuit breaker

STALL_IND BOOLEAN 0=False Input signal for showing the motor is not stalling

ST_EMERG_ENA BOOLEAN 0=False Enable emergency start to disable lock of start ofmotor

Table 411: STTPMSU Output signals

Name Type DescriptionOPR_IIT BOOLEAN Operate/trip signal for thermal stress.

OPR_STALL BOOLEAN Operate/trip signal for stalling protection.

MOT_START BOOLEAN Signal to show that motor startup is in progress

LOCK_START BOOLEAN Lock out condition for restart of motor.



4.8.7 SettingsTable 412: STTPMSU Group settings

Parameter Values (Range) Unit Step Default DescriptionStart detection A 0.1...10.0 xIn 0.1 1.5 Current value for detecting starting of

motor.

Motor start-up A 1.0...10.0 xIn 0.1 2.0 Motor starting current

Motor start-up time 1...80 s 1 5 Motor starting time

Lock rotor time 2...120 s 1 10 Permitted stalling time

Str over delay time 0...60000 ms 1 100 Time delay to check for completion ofmotor startup period

Table 413: STTPMSU Non group settings



Operation mode 1=IIt2=IIt, CB3=IIt + stall4=IIt + stall, CB

1=IIt Motor start-up operation mode

Counter Red rate 2.0...250.0 s/h 0.1 60.0 Start time counter reduction rate

Cumulative time Lim 1...500 s 1 10 Cumulative time based restart inhibit limit

Emg start Red rate 0.00...100.00 % 0.01 20.00 Start time reduction factor whenemergency start is On

Restart inhibit time 0...250 min 1 30 Time delay between consecutive startups

Motor standstill A 0.05...0.20 xIn 0.01 0.12 Current limit to check for motor standstillcondition

4.8.8 Monitored dataTable 414: STTPMSU Monitored data

Name Type Values (Range) Unit DescriptionSTART_CNT INT32 0...999999 Number of motor start-

ups occurred

START_TIME FLOAT32 0.0...999.9 s Measured motor lateststartup time in sec

T_ST_CNT FLOAT32 0.0...99999.9 s Cumulated start-up timein sec

T_RST_ENA INT32 0...999 min Time left for restart whenlockstart is enabled inminutes




Name Type Values (Range) Unit DescriptionIIT_RL FLOAT32 0.00...100.00 % Thermal stress relative

to set maximum thermalstress

STALL_RL FLOAT32 0.00...100.00 % Start time relative to theoperate time for stallcondition

STTPMSU Enum 1=on2=blocked3=test4=test/blocked5=off

Status

4.8.9 Technical dataTable 415: STTPMSU Technical data


measured: fn ±2 Hz



IFault = 1.1 x set Startdetection A 27 ms 30 ms 34 ms



1) Current before = 0.0 x In, fn = 50 Hz, overcurrent in one phase, results based on statisticaldistribution of 1000 measurements


4.9 Multipurpose protection MAPGAPC




Multipurpose protection MAPGAPC MAP MAP




GUID-A842A2C8-0188-4E01-8490-D00F7D1D8719 V2 EN


4.9.3 FunctionalityThe multipurpose protection function MAPGAPC is used as a general protectionwith many possible application areas as it has flexible measuring and settingfacilities. The function can be used as an under- or overprotection with a settableabsolute hysteresis limit. The function operates with the definite time (DT)characteristics.



The operation of the multipurpose protection function can be described using amodule diagram. All the modules in the diagram are explained in the next sections.

AI_VALUE OPERATELeveldetector

BlockinglogicBLOCK

START

Timer

ENA_ADDt

GUID-50AA4A14-7379-43EB-8FA0-6C20C12097AC V1 EN


Level detectorThe level detector compares AI_VALUE to the Start value setting. The Operationmode setting defines the direction of the level detector.



Table 416: Operation mode types

Operation Mode Description"Under" If the input signal AI_VALUE is lower than the

set value of the Start value setting, the leveldetector enables the timer module.

"Over" If the input signal AI_VALUE exceeds the setvalue of the Start value setting, the level detectorenables the timer module.

The Absolute hysteresis setting can be used for preventing unnecessary oscillationsif the input signal is slightly above or below the Start value setting. After leavingthe hysteresis area, the start condition has to be fulfilled again and it is notsufficient for the signal to only return to the hysteresis area. If the ENA_ADD inputis activated, the threshold value of the internal comparator is the sum of the Startvalue Add and Start value settings. The resulting threshold value for thecomparator can be increased or decreased depending on the sign and value of theStart value Add setting.

TimerOnce activated, the timer activates the START output. The time characteristic isaccording to DT. When the operation timer has reached the value set by Operatedelay time, the OPERATE output is activated. If the starting condition disappearsbefore the module operates, the reset timer is activated. If the reset timer reachesthe value set by Reset delay time, the operation timer resets and the START outputis deactivated.






4.9.5 ApplicationThe function block can be used for any general analog signal protection, eitherunderprotection or overprotection. The setting range is wide, allowing variousprotection schemes for the function. Thus, the absolute hysteresis can be set to avalue that suits the application.

The temperature protection using the RTD sensors can be done using the functionblock. The measured temperature can be fed from the RTD sensor to the functioninput that detects too high temperatures in the motor bearings or windings, forexample. When the ENA_ADD input is enabled, the threshold value of the internalcomparator is the sum of the Start value Add and Start value settings. This allows atemporal increase or decrease of the level detector depending on the sign and valueof the Start value Add setting, for example, when the emergency start is activated.If, for example, Start value is 100, Start value Add is 20 and the ENA_ADD input isactive, the input signal needs to rise above 120 before MAPGAPC operates.

4.9.6 SignalsTable 417: MAPGAPC Input signals

Name Type Default DescriptionAI_VALUE FLOAT32 0.0 Analog input value


ENA_ADD BOOLEAN 0=False Enable start added

Table 418: MAPGAPC Output signals


START BOOLEAN Start

4.9.7 SettingsTable 419: MAPGAPC Group settings

Parameter Values (Range) Unit Step Default DescriptionStart value -10000.0...10000.0 0.1 0.0 Start value

Start value Add -100.0...100.0 0.1 0.0 Start value Add




Table 420: MAPGAPC Non group settings



Operation mode 1=Over2=Under

1=Over Operation mode


Absolute hysteresis 0.01...100.00 0.01 0.10 Absolute hysteresis for operation

4.9.8 Monitored dataTable 421: MAPGAPC Monitored data


operate time

MAPGAPC Enum 1=on2=blocked3=test4=test/blocked5=off

Status

4.9.9 Technical dataTable 422: MAPGAPC Technical data

Characteristic ValueOperation accuracy ±1.0% of the set value or ±20 ms



Section 5 Protection related functions

5.1 Three-phase inrush detector INRPHAR




Three-phase inrush detector INRPHAR 3I2f> 68


A070377 V1 EN


5.1.3 FunctionalityThe transformer inrush detection INRPHAR is used to coordinate transformerinrush situations in distribution networks.

Transformer inrush detection is based on the following principle: the output signalBLK2H is activated once the numerically derived ratio of second harmonic currentI_2H and the fundamental frequency current I_1H exceeds the set value.

The operate time characteristic for the function is of definite time (DT) type.

The function contains a blocking functionality. Blocking deactivates all outputsand resets timers.


1MRS756887 G Section 5Protection related functions


The operation of an inrush current detection function can be described using amodule diagram. All the modules in the diagram are explained in the next sections.

A070694 V2 EN

Figure 253: Functional module diagram. I_1H and I_2H represent fundamentaland second harmonic values of phase currents.

I_2H/I_1HThis module calculates the ratio of the second harmonic (I_2H) and fundamentalfrequency (I_1H) phase currents. The calculated value is compared to the set Startvalue. If the calculated value exceeds the set Start value, the module output isactivated.

Level detectorThe output of the phase specific level detector is activated when the fundamentalfrequency current I_1H exceeds five percent of the nominal current.

TimerOnce activated, the timer runs until the set Operate delay time value. The timecharacteristic is according to DT. When the operation timer has reached theOperate delay time value, the BLK2H output is activated. After the timer haselapsed and the inrush situation still exists, the BLK2H signal remains active untilthe I_2H/I_1H ratio drops below the value set for the ratio in all phases, that is,until the inrush situation is over. If the drop-off situation occurs within the operatetime up counting, the reset timer is activated. If the drop-off time exceeds Resetdelay time, the operate timer is reset.

The BLOCK input can be controlled with a binary input, a horizontalcommunication input or an internal signal of the relay program. The activation ofthe BLOCK input prevents the BLK2H output from being activated.

Section 5 1MRS756887 GProtection related functions


It is recommended to use the second harmonic and the waveformbased inrush blocking from the TR2PTDF function if available.

5.1.5 ApplicationTransformer protections require high stability to avoid tripping during magnetizinginrush conditions. A typical example of an inrush detector application is doublingthe start value of an overcurrent protection during inrush detection.

The inrush detection function can be used to selectively block overcurrent and earth-fault function stages when the ratio of second harmonic component over thefundamental component exceeds the set value.

Other applications of this function include the detection of inrush in linesconnected to a transformer.

A070695 V2 EN

Figure 254: Inrush current in transformer



It is recommended to use the second harmonic and the waveformbased inrush blocking from the transformer differential protectionfunction TR2PTDF if available.

5.1.6 SignalsTable 423: INRPHAR Input signals

Name Type Default DescriptionI_2H_A SIGNAL 0 Second harmonic phase A current

I_1H_A SIGNAL 0 Fundamental frequency phase A current

I_2H_B SIGNAL 0 Second harmonic phase B current

I_1H_B SIGNAL 0 Fundamental frequency phase B current

I_2H_C SIGNAL 0 Second harmonic phase C current

I_1H_C SIGNAL 0 Fundamental frequency phase C current

BLOCK BOOLEAN 0=False Block input status

Table 424: INRPHAR Output signals

Name Type DescriptionBLK2H BOOLEAN Second harmonic based block

5.1.7 SettingsTable 425: INRPHAR Group settings

Parameter Values (Range) Unit Step Default DescriptionStart value 5...100 % 1 20 Ratio of the 2. to the 1. harmonic leading

to restraint


Table 426: INRPHAR Non group settings






5.1.8 Monitored dataTable 427: INRPHAR Monitored data

Name Type Values (Range) Unit DescriptionINRPHAR Enum 1=on


Status

5.1.9 Technical dataTable 428: INRPHAR Technical data

Characteristic ValueOperation accuracy At the frequency f = fn

Current measurement:±1.5% of the set value or ±0.002 x InRatio I2f/I1f measurement:±5.0% of the set value

Reset time +35 ms / -0 ms


Operate time accuracy +35 ms / -0 ms

5.2 Circuit breaker failure protection CCBRBRF




Circuit breaker failure protection CCBRBRF 3I>/Io>BF 51BF/51NBF


A070436 V4 EN




5.2.3 FunctionalityThe breaker failure function CCBRBRF is activated by trip commands from theprotection functions. The commands are either internal commands to the terminalor external commands through binary inputs. The start command is always adefault for three-phase operation. CCBRBRF includes a three-phase conditional orunconditional re-trip function, and also a three-phase conditional back-up tripfunction.

CCBRBRF uses the same levels of current detection for both re-trip and back-uptrip. The operating values of the current measuring elements can be set within apredefined setting range. The function has two independent timers for trippurposes: a re-trip timer for the repeated tripping of its own breaker and a back-uptimer for the trip logic operation for upstream breakers. A minimum trip pulselength can be set independently for the trip output.

The function contains a blocking functionality. It is possible to block the functionoutputs, if desired.


The operation of the breaker failure protection can be described using a modulediagram. All the modules in the diagram are explained in the next sections. Alsofurther information on the retrip and backup trip logics is given in sub-modulediagrams.

TRRET

BLOCK

CB_FAULT

TRBUBack-up

triplogic

POSCLOSESTART

Io

Retriplogic

Leveldetector

2

Leveldetector

1

I_AI_BI_C

tTimer 2

tTimer 3

CB_FAULT_AL

Start logic

tTimer 1

A070445 V3 EN

Figure 256: Functional module diagram. I_A, I_B and I_C represent phasecurrents and Io residual current.



Level detector 1The measured phase currents are compared phasewise to the set Current value. Ifthe measured value exceeds the set Current value, the level detector reports theexceeding of the value to the start, retrip and backup trip logics. The parametershould be set low enough so that breaker failure situations with small fault currentor high load current can be detected. The setting can be chosen in accordance withthe most sensitive protection function to start the breaker failure protection.

Level detector 2The measured residual current is compared to the set Current value Res. If themeasured value exceeds the set Current value Res, the level detector reports theexceeding of the value to the start and backup trip logics. In high-impedanceearthed systems, the residual current at phase-to-earth faults is normally muchsmaller than the short circuit currents. To detect a breaker failure at single-phaseearth faults in these systems, it is necessary to measure the residual currentseparately. In effectively earthed systems, also the setting of the earth-fault currentprotection can be chosen at a relatively low current level. The current settingshould be chosen in accordance with the setting of the sensitive earth-fault protection.

Start logicThe start logic is used to manage the starting of the timer 1 and timer 2. It alsoresets the function after the circuit breaker failure is handled. On the rising edge ofthe START input, the enabling signal is send to the timer 1 and timer 2.

Once the timer 1 and timer 2 are activated, CCBRBRF can be reset only after thetimers have reached the value set with the Retrip time and CB failure delay settingsrespectively and the 150ms time elapse after the timer 1 and timer 2 has beenactivated. The 150ms time elapse is provided to prevent malfunctioning due tooscillation in the starting signal.

In case the setting Start latching mode is set to "Level sensitive", the CCBRBRF isreset immediately after the START signal is deactivated. The recommended settingvalue is "Rising edge".

The resetting of the function depends on the CB failure mode setting. If CB failuremode is set to "Current", the resetting logic further depends on the CB failure tripmode setting.

• If CB failure trip mode is set to "1 out of 3", the resetting logic requires thatthe values of all the phase currents drop below the Current value setting.

• If CB failure trip mode is set to "1 out of 4", the resetting logic requires thateither the values of the phase currents or the residual current drops below theCurrent value and Current value Res setting respectively.

• If CB failure trip mode is set to "2 out of 4", the resetting logic requires thatthe values of all the phase currents and the residual current drop below theCurrent value and Current value Res setting respectively.



If CB failure mode is set to the "Breaker status" mode, the resetting logic requiresthat the circuit breaker is in the open condition. If the CB failure mode setting is setto "Both", the logic resets when any of the above criteria is fulfilled.

Also the activation of the BLOCK input resets the function.

AND

AND

ANDTimer 2 elapsed

From Timer 2

Timer 1 elapsedFrom Timer 1

TON150.0 ms

AND

CB failure mode ”Current”

CB failure mode ”Breaker status”

POSCLOSE

CB failure trip mode “1 out of 4"

I0 >From Level detector 2

I >From Level detector 1

AND

Set

ResetEnable timer

BLOCK

AND

OR

CB failure trip mode “2 out of 4"

I0 >From Level detector 2


AND

OR

Start latching mode ”Level sensitive”

AND

START

GUID-61D73737-798D-4BA3-9CF2-56D57719B03D V3 EN

Figure 257: Start logic

Timer 1Once activated, the timer runs until the set Retrip time value has elapsed. The timecharacteristic is according to DT. When the operation timer has reached the valueset with Retrip time, the retrip logic is activated. A typical setting is 0 - 50 ms.

Timer 2Once activated, the timer runs until the set CB failure delay value has elapsed. Thetime characteristic is according to DT. When the operation timer has reached theset maximum time value CB failure delay, the backup trip logic is activated. Thevalue of this setting is made as low as possible at the same time as any unwantedoperation is avoided. A typical setting is 90 - 150 ms, which is also dependent onthe retrip timer.



The minimum time delay for the retrip can be estimated as:

CBfailuredelay Retriptime t t tcbopen BFP reset margin≥ + + +_


tcbopen maximum opening time for the circuit breaker

tBFP_reset maximum time for the breaker failure protection to detect the correct breaker function (thecurrent criteria reset)

tmargin safety margin

It is often required that the total fault clearance time is less than the given criticaltime. This time often depends on the ability to maintain transient stability in case ofa fault close to a power plant.

GUID-1A2C47ED-0DCF-4225-9294-2AEC97C14D5E V1 EN

Figure 258: Timeline of the breaker failure protection

Timer 3This module is activated by the CB_FAULT signal. Once activated, the timer runsuntil the set CB fault delay value has elapsed. The time characteristic is accordingto DT. When the operation timer has reached the maximum time value CB faultdelay, the CB_FAULT_AL output is activated. After the set time, an alarm is givenso that the circuit breaker can be repaired. A typical value is 5 s.

Retrip logicThe retrip logic provides the TRRET output, which can be used to give a retripsignal for the main circuit breaker. Timer 1 activates the retrip logic. The operation



of the retrip logic depends on the CB fail retrip mode setting. The retrip logic isinactive if the CB fail retrip mode setting is set to "Off".

If CB fail retrip mode is set to the "Current check" mode, the activation of theretrip output TRRET depends on the CB failure mode setting.

• If CB failure mode is set to the "Current" mode, TRRET is activated when thevalue of any phase current exceeds the Current value setting. The TRREToutput remains active for the time set with the Trip pulse time setting or untilall phase current values drop below the Current value setting, whichever islonger.

• If CB failure mode is set to the "Breaker status" mode, TRRET is activated ifthe circuit breaker is in the closed position. The TRRET output remains activefor the time set with the Trip pulse time setting or the time the circuit breakeris in the closed position, whichever is longer.

• If CB failure mode is set to "Both", TRRET is activated when either of the"Breaker status" or "Current" mode condition is satisfied.

If CB fail retrip mode is set to the "Without check" mode, TRRET is activated oncethe timer 1 is activated without checking the current level. The TRRET outputremains active for a fixed time set with the Trip pulse timer setting.

The activation of the BLOCK input or the CB_FAULT_AL output deactivates theTRRET output.

POSCLOSE



OR

AND

AND

CB fail retrip mode ”Without check”

CB fail retrip mode ”Current check”



CB failure mode ”Both”

AND

AND

AND

OR

OR

AND TRRET

BLOCK

CB_FAULT_ALFrom Timer 3

GUID-BD64DEDB-758C-4F53-8287-336E43C750F2 V2 EN

Figure 259: Retrip logic

Backup trip logicThe backup trip logic provides the TRBU output which can be used to trip theupstream backup circuit breaker when the main circuit breaker fails to clear thefault. The backup trip logic is activated by the timer 2 module or timer-enabling



signal from the start logic module (rising edge of the START input detected), andsimultaneously CB_FAULT_AL is active. The operation of the backup logicdepends on the CB failure mode setting.

If the CB failure mode is set to "Current", the activation of TRBU depends on theCB failure trip mode setting as follows:

• If CB failure trip mode is set to "1 out of 3", the failure detection is based onany of the phase currents exceeding the Current value setting. Once TRBU isactivated, it remains active for the time set with the Trip pulse time setting oruntil the values of all the phase currents drop below the Current value setting,whichever takes longer.

• If CB failure trip mode is set to "1 out of 4", the failure detection is based oneither a phase current or a residual current exceeding the Current value orCurrent value Res setting respectively. Once TRBU is activated, it remainsactive for the time set with the Trip pulse time setting or until the values of allthe phase currents or residual currents drop below the Current value andCurrent value Res setting respectively, whichever takes longer.

• If CB failure trip mode is set to "2 out of 4", the failure detection requires thata phase current and a residual current both exceed the Current value orCurrent value Res setting respectively. Once TRBU is activated, it remainsactive for the time set with the Trip pulse time setting or until the values of allthe phase currents and residual currents drop below the Current value andCurrent value Res setting respectively, whichever takes longer.

In most applications, "1 out of 3" is sufficient.

If the CB failure mode is set to "Breaker status", the TRBU output is activated if thecircuit breaker is in the closed position. Once activated, the TRBU output remainsactive for the time set with the Trip pulse time setting or the time the circuit breakeris in the closed position, whichever is longer.

If the CB failure mode setting is set to "Both", TRBU is activated when the"Breaker status" or "Current" mode conditions are satisfied.

The activation of the BLOCK input deactivates the TRBU output.



POSCLOSE

Enable timerFrom Start logic




AND

CB failure trip mode”1 out of 3"

CB failure trip mode ”1 out of 4"

AND

AND

AND

CB failure trip mode ”2 out of 4"

OR

OR

AND

I >From level detector 1

TRBU

Io >From level detector 2

AND

OROR

OR


AND

AND

BLOCK


CB_FAULT_ALFrom Timer 3

AND

OR

GUID-30BB8C04-689A-4FA5-85C4-1DF5E3ECE179 V3 EN

Figure 260: Backup trip logic

5.2.5 ApplicationThe n-1 criterion is often used in the design of a fault clearance system. This meansthat the fault is cleared even if some component in the fault clearance system isfaulty. A circuit breaker is a necessary component in the fault clearance system.For practical and economical reasons, it is not feasible to duplicate the circuitbreaker for the protected component, but breaker failure protection is used instead.

The breaker failure function issues a backup trip command to adjacent circuitbreakers in case the original circuit breaker fails to trip for the protectedcomponent. The detection of a failure to break the current through the breaker ismade by measuring the current or by detecting the remaining trip signal(unconditional).

CCBRBRF can also retrip. This means that a second trip signal is sent to theprotected circuit breaker. The retrip function is used to increase the operationalreliability of the breaker. The function can also be used to avoid backup tripping ofseveral breakers in case mistakes occur during IED maintenance and tests.



CCBRBRF is initiated by operating different protection functions or digital logicsinside the IED. It is also possible to initiate the function externally through a binaryinput.

CCBRBRF can be blocked by using an internally assigned signal or an externalsignal from a binary input. This signal blocks the function of the breaker failureprotection even when the timers have started or the timers are reset.

The retrip timer is initiated after the start input is set to true. When the pre-definedtime setting is exceeded, CCBRBRF issues the retrip and sends a trip command,for example, to the circuit breaker's second trip coil. Both a retrip with currentcheck and an unconditional retrip are available. When a retrip with current check ischosen, the retrip is performed only if there is a current flow through the circuitbreaker.

The backup trip timer is also initiated at the same time as the retrip timer. IfCCBRBRF detects a failure in tripping the fault within the set backup delay time,which is longer than the retrip time, it sends a backup trip signal to the chosenbackup breakers. The circuit breakers are normally upstream breakers which feedfault current to a faulty feeder.

The backup trip always includes a current check criterion. This means that thecriterion for a breaker failure is that there is a current flow through the circuitbreaker after the set backup delay time.

A070696 V2 EN

Figure 261: Typical breaker failure protection scheme in distribution substations



5.2.6 SignalsTable 429: CCBRBRF Input signals





BLOCK BOOLEAN 0=False Block CBFP operation

START BOOLEAN 0=False CBFP start command

POSCLOSE BOOLEAN 0=False CB in closed position

CB_FAULT BOOLEAN 0=False CB faulty and unable to trip

Table 430: CCBRBRF Output signals

Name Type DescriptionCB_FAULT_AL BOOLEAN Delayed CB failure alarm

TRBU BOOLEAN Backup trip

TRRET BOOLEAN Retrip

5.2.7 SettingsTable 431: CCBRBRF Non group settings



Current value 0.05...2.00 xIn 0.05 0.30 Operating phase current

Current value Res 0.05...1.00 xIn 0.05 0.30 Operating residual current

CB failure trip mode 1=2 out of 42=1 out of 33=1 out of 4

1=2 out of 4 Backup trip current check mode

CB failure mode 1=Current2=Breaker status3=Both

1=Current Operating mode of function

CB fail retrip mode 1=Off2=Without Check3=Current check

1=Off Operating mode of retrip logic

Retrip time 0...60000 ms 10 20 Delay timer for retrip

CB failure delay 0...60000 ms 10 150 Delay timer for backup trip

CB fault delay 0...60000 ms 10 5000 Circuit breaker faulty delay

Measurement mode 2=DFT3=Peak-to-Peak

2=DFT Phase current measurement mode offunction

Trip pulse time 0...60000 ms 10 150 Pulse length of retrip and backup tripoutputs

Start latching mode 1=Rising edge2=Level sensitive

1=Rising edge Start reset delayed or immediately



5.2.8 Monitored dataTable 432: CCBRBRF Monitored data

Name Type Values (Range) Unit DescriptionCCBRBRF Enum 1=on


Status

5.2.9 Technical dataTable 433: CCBRBRF Technical data


measured: fn ±2 Hz



5.2.10 Technical revision historyTable 434: CCBRBRF Technical revision history

Technical revision ChangeB Default trip pulse time changed to 150 ms

C Added new setting parameter Start latchingmode.Maximum value changed to 2.00 xIn for theCurrent value setting.

5.3 Master trip TRPPTRC




Master trip TRPPTRC Master Trip 94/86




A071286 V2 EN


5.3.3 FunctionalityThe master trip function TRPPTRC is used as a trip command collector andhandler after the protection functions. The features of this function influence thetrip signal behavior of the circuit breaker. The minimum trip pulse length can beset when the non-latched mode is selected. It is also possible to select the latched orlockout mode for the trip signal.


When the TRPPTRC function is disabled, all trip outputs intendedto go through the function to the circuit breaker trip coil are blocked!

The operation of the tripping logic function can be described with a modulediagram. All the modules in the diagram are explained in the next sections.

A070882 V4 EN


TimerThe duration of the TRIP output signal from TRPPTRC can be adjusted with theTrip pulse time setting when the "Non-latched" operation mode is used. The pulselength should be long enough to secure the opening of the breaker. For three-poletripping, TRPPTRC has a single input OPERATE, through which all trip outputsignals are routed from the protection functions within the IED, or from externalprotection functions via one or more of the IED's binary inputs. The function has a



single trip output TRIP for connecting the function to one or more of the IED'sbinary outputs, and also to other functions within the IED requiring this signal.

The BLOCK input blocks the TRIP output and resets the timer.

Lockout logicTRPPTRC is provided with possibilities to activate a lockout. When activated, thelockout can be manually reset after checking the primary fault by activating theRST_LKOUT input or from the LHMI clear menu parameter. When using the"Latched" mode, the resetting of the TRIP output can be done similarly as whenusing the "Lockout" mode. It is also possible to reset the "Latched" mode remotelythrough a separate communication parameter.

The minimum pulse trip function is not active when using the"Lockout" or "Latched" modes but only when the "Non-latched"mode is selected.

The CL_LKOUT and TRIP outputs can be blocked with the BLOCK input.

Table 435: Operation modes for the TRPPTRC trip output

Mode OperationNon-latched The Trip pulse length parameter gives the

minimum pulse length for TRIP

Latched TRIP is latched ; both local and remote clearingis possible.

Lockout TRIP is locked and can be cleared only locallyvia menu or the RST_LKOUT input.

5.3.5 ApplicationAll trip signals from different protection functions are routed through the trip logic.The most simplified application of the logic function is linking the trip signal andensuring that the signal is long enough.

The tripping logic in the protection relay is intended to be used in the three-phasetripping for all fault types (3ph operating). To prevent the closing of a circuitbreaker after a trip, TRPPTRC can block the CBXCBR closing.

TRPPTRC is intended to be connected to one trip coil of the corresponding circuitbreaker. If tripping is needed for another trip coil or another circuit breaker whichneeds, for example, different trip pulse time, another trip logic function can beused. The two instances of the PTRC function are identical, only the names of thefunctions, TRPPTRC1 and TRPPTRC2, are different. Therefore, even if allreferences are made only to TRPPTRC1, they also apply to TRPPTRC2.



The inputs from the protection functions are connected to the OPERATE input.Usually, a logic block OR is required to combine the different function outputs tothis input. The TRIP output is connected to the binary outputs on the IO board.This signal can also be used for other purposes within the IED, for example whenstarting the breaker failure protection.

TRPPTRC is used for simple three-phase tripping applications.

BI#4Lock-outreset

OR

PO#1

BI#2

TRPPTRC

OPERATE

RST_LKOUT

TRIP

CCRBRF-trret

T1PTTR-operate

CBXCBR-open

PHLPTOC-operate

PHHPTOC1-operate

PHHPTOC2-operate

PHIPTOC-operate

NSPTOC1-operate

NSPTOC2-operate

EFLPTOC1-operate

EFHPTOC-operate

EFIPTOC-operate

PDNSPTOC-operate

EFLPTOC2-operate

ARCPSARC1-operate

ARCPSARC2-operate

ARCPSARC3-operate

DARREC-open cb

BLOCK CL_LKOUT

A070881 V2 EN

Figure 264: Typical TRPPTRC connection

5.3.6 SignalsTable 436: TRPPTRC Input signals

Name Type Default DescriptionBLOCK BOOLEAN 0=False Block of function

OPERATE BOOLEAN 0=False Request to trip circuit breaker.

RST_LKOUT BOOLEAN 0=False Input for resetting the circuit breaker lockoutfunction

Table 437: TRPPTRC Output signals

Name Type DescriptionTRIP BOOLEAN General trip output signal

CL_LKOUT BOOLEAN Circuit breaker lockout output (set until reset)



5.3.7 SettingsTable 438: TRPPTRC Non group settings



Trip pulse time 20...60000 ms 1 150 Minimum duration of trip output signal

Trip output mode 1=Non-latched2=Latched3=Lockout

2=Latched Select the operation mode for trip output

5.3.8 Monitored dataTable 439: TRPPTRC Monitored data

Name Type Values (Range) Unit DescriptionTRPPTRC Enum 1=on


Status

5.3.9 Technical revision historyTable 440: TRPPTRC Technical revision history


C -

5.4 Binary signal transfer BSTGGIO




Binary signal transfer BSTGGIO BST BST




GUID-6D70959C-EC59-4C72-85E5-9BE89ED39DBB V1 EN


5.4.3 FunctionalityThe binary signal transfer function BSTGGIO is used for transferring binarysignals between the local and remote end line differential protection IEDs. Thefunction includes eight binary signals that are transferred in the protectioncommunication telegram and can be freely configured and used for any purpose inthe line differential application.

BSTGGIO transfers binary data continuously over the protection communicationchannel between the terminals. Each of the eight signals are bidirectional and thebinary data sent locally is available remotely as a received signal.

BSTGGIO includes a minimum pulse time functionality for the received binarysignals. Each received signal has its own minimum pulse time setting parameter.

BSTGGIO includes two alarm output signals. The SEND_SIG_A output signal isupdated according to the status of the sent binary signals. The RECV_SIG_Aoutput signal is updated according to the status of the received binary signals. Eachsignal can be separately included or excluded from the alarm logic with a settingparameter.

5.4.4 Operation principleThe Signal 1...8 mode setting can be used for changing the operation of thebidirectional signal channel. The signal channel can be disabled by setting thecorresponding parameter value to “Not in use”. When the signal channel isdisabled locally or remotely, the corresponding RECV_SIG_1...8 signal statusis always false on both ends.



GUID-54526C83-99FA-478B-877A-394234289F91 V1 EN


Binary signal sendThe status of the inputs is continuously sent in the line differential protectiontelegrams. SEND_SIG_A can be used for alarming based on the status ofSEND_SIG_1...8. By selecting the signal mode as "In use, alarm sel.", thesending status of the corresponding signal affects also the activation criteria ofSEND_SIG_A. Further, in case more than one signal channels are selected into thealarm logic, the activation criteria can be defined according to "Any of selected"(OR) or "All of selected" (AND).

Binary signal receiveThe function receives continuous binary data within the protection telegrams fromthe remote end IED. This received binary data status is then available as theRECV_SIG_1...8 outputs on the local end IED. RECV_SIG_A can be used foralarming based on the status of RECV_SIG_1...8. By selecting the signal modeas "In use, alarm sel.", the received status of the corresponding signal affects theactivation criteria of RECV_SIG_A. Further, in case more than one signal channelsare selected into the alarm logic, the activation criteria can be defined according to"Any of selected" (OR) or "All of selected" (AND). Each signal has also the Pulsetime 1...8 setting that defines the minimum pulse length for RECV_SIG_1...8.Also, in case the protection communication supervision detects a failure in thecommunication, the RECV_SIG_1...8 outputs are not set to false sooner thanthe minimum pulse length defined is first ensured for each signal.

5.4.5 Application

Among with the analog data, the binary data can also be exchanged with the linedifferential protection IEDs. The usage of the binary data is application specific



and can vary in each separate case. The demands for the speed of the binary signalsvary depending on the usage of the data. When the binary data is used as blockingsignals for the line differential protection, the transfer response is extremely high.Binary signal interchange can be used in applications such as:

• Remote position indications• Inter-tripping of the circuit breakers on both line ends• Blocking of the line differential protection during transformer inrush or current

circuit supervision failure• Protection schemes; blocking or permissive• Remote alarming.

The figure shows the overall chain to transfer binary data in an exampleapplication. The position indication of the local circuit breaker is connected to theIED’s input interface and is then available for the IED configuration. The circuitbreaker position indication is connected to the first input of BSTGGIO which isused to send information to the remote end via communication. In the remote end,this information is handled as a remote circuit breaker open position and it isavailable from the first output of BSTGGIO. This way the information can beexchanged.

GUID-85FE5892-DDA5-4ED9-9412-A3A48E364EFC V1 EN

Figure 267: Example of usage of binary signal transfer for position indicationchange



5.4.6 SignalsTable 441: BSTGGIO Input signals

Name Type Default DescriptionSEND_SIG_1 BOOLEAN 0=False Send signal 1 state

SEND_SIG_2 BOOLEAN 0=False Send signal 2 state







Table 442: BSTGGIO Output signals

Name Type DescriptionRECV_SIG_1 BOOLEAN Receive signal 1 state

RECV_SIG_2 BOOLEAN Receive signal 2 state







SEND_SIG_A BOOLEAN Binary signal transfer sending alarm state

RECV_SIG_A BOOLEAN Binary signal transfer receive alarm state

5.4.7 SettingsTable 443: BSTGGIO Group settings

Parameter Values (Range) Unit Step Default DescriptionSignal 1 mode 1=In use

2=In use, alarm sel.3=Not in use

2=In use, alarmsel.

Operation mode for signal 1

Signal 2 mode 1=In use2=In use, alarm sel.3=Not in use

2=In use, alarmsel.

Operation mode for signal 2


1=In use Operation mode for signal 3






Parameter Values (Range) Unit Step Default DescriptionSignal 5 mode 1=In use

2=In use, alarm sel.3=Not in use








Pulse time 1 0...60000 ms 1 0 Minimum pulse time for received signal 1








Table 444: BSTGGIO Non group settings

Parameter Values (Range) Unit Step Default DescriptionAlarm mode 1=Any of selected

2=All of selected 1=Any of selected Selects the used alarm logic mode for

activating SEND_SIG_A andRECV_SIG_A

5.4.8 Technical dataTable 445: BSTGGIO Technical data

Characteristic ValueSignalling delay Fiber optic link < 5 ms

Galvanic pilotwire link < 10 ms

5.5 Emergency startup ESMGAPC

5.5.1 IdentificationFunctional description IEC 61850



Emergency startup ESMGAPC ESTART ESTART




GUID-3AF99427-2061-47E1-B3AB-FD1C9BF98E76 V1 EN


5.5.3 FunctionalityAn emergency condition can arise in cases where the motor needs to be starteddespite knowing that this can increase the temperature above limits or cause athermal overload that can damage the motor. The emergency startup ESMGAPCallows motor startups during such emergency conditions. ESMGAPC is only toforce the IED to allow the restarting of the motor. After the emergency start inputis activated, the motor can be started normally. ESMGAPC itself does not actuallyrestart the motor.



The operation of the emergency startup can be described using a module diagram.All the modules in the diagram are explained in the next sections.

GUID-18128621-4A78-45D0-A788-9116B5213449 V1 EN


Standstill detectorThe module detects if the motor is in a standstill condition. The standstill conditioncan be detected based on the phase current values. If all three phase currents arebelow the set value of Motor standstill A, the motor is considered to be in astandstill condition.



TimerThe timer is a fixed 10-minute timer that is activated when the ST_EMERG_RQinput is activated and motor standstill condition is fulfilled. Thus, the activation ofthe ST_EMERG_RQ input activates the ST_EMERG_ENA output, provided that themotor is in a standstill condition. The ST_EMERG_ENA output remains active for10 minutes or as long as the ST_EMERG_RQ input is high, whichever takes longer.

The activation of the BLOCK input blocks and also resets the timer.

The function also provides the ST_EMERG_ENA output change date and time,T_ST_EMERG. The information is available in the monitored data view.

5.5.5 ApplicationIf the motor needs to be started in an emergency condition at the risk of damagingthe motor, all the external restart inhibits are ignored, allowing the motor to berestarted. Furthermore, if the calculated thermal level is higher than the restartinhibit level at an emergency start condition, the calculated thermal level is setslightly below the restart inhibit level. Also, if the register value of the cumulativestartup time counter exceeds the restart inhibit level, the value is set slightly belowthe restart disable value to allow at least one motor startup.

The activation of the ST_EMERG_RQ digital input allows to perform emergencystart. The IED is forced to a state which allows the restart of motor, and theoperator can now restart the motor. A new emergency start cannot be made untilthe 10 minute time-out has passed or until the emergency start is released,whichever takes longer.

The last change of the emergency start output signal is recorded.

5.5.6 SignalsTable 446: ESMGAPC Input signals





ST_EMERG_RQ BOOLEAN 0=False Emergency start input

Table 447: ESMGAPC Output signals

Name Type DescriptionST_EMERG_ENA BOOLEAN Emergency start



5.5.7 SettingsTable 448: ESMGAPC Group settings

Parameter Values (Range) Unit Step Default DescriptionMotor standstill A 0.05...0.20 xIn 0.01 0.12 Current limit to check for motor standstill

condition

Table 449: ESMGAPC Non group settings



5.5.8 Monitored dataTable 450: ESMGAPC Monitored data

Name Type Values (Range) Unit DescriptionT_ST_EMERG Timestamp Emergency start

activation timestamp

ESMGAPC Enum 1=on2=blocked3=test4=test/blocked5=off

Status

5.5.9 Technical dataTable 451: ESMGAPC Technical data


±1.5% of the set value or ±0.002 × Un



Section 6 Supervision functions

6.1 Trip circuit supervision TCSSCBR




Trip circuit supervision TCSSCBR TCS TCM


A070788 V1 EN


6.1.3 FunctionalityThe trip circuit supervision function TCSSCBR is designed to supervise the controlcircuit of the circuit breaker. The invalidity of a control circuit is detected by usinga dedicated output contact that contains the supervision functionality.The failure ofa circuit is reported to the corresponding function block in the IED configuration.

The function starts and operates when TCSSCBR detects a trip circuit failure. Theoperating time characteristic for the function is DT. The function operates after apredefined operating time and resets when the fault disappears.

The function contains a blocking functionality. Blocking deactivates the ALARMoutput and resets the timer.


The operation of trip circuit supervision can be described by using a modulediagram. All the modules in the diagram are explained in the next sections.

1MRS756887 G Section 6Supervision functions


A070785 V2 EN


TCS statusThis module receives the trip circuit status from the hardware. A detected failure inthe trip circuit activates the timer.

TimerOnce activated, the timer runs until the set value of Operate delay time has elapsed.The time characteristic is according to DT. When the operation timer has reachedthe maximum time value, the ALARM output is activated. If a drop-off situationoccurs during the operate time up counting, the fixed 0.5 s reset timer is activated.After that time, the operation timer is reset.

The BLOCK input can be controlled with a binary input, a horizontalcommunication input or an internal signal of the relay program. The activation ofthe BLOCK input prevents the ALARM output to be activated.

6.1.5 ApplicationTCSSCBR detects faults in the electrical control circuit of the circuit breaker. Thefunction can supervise both open and closed coil circuits. This kind of supervisionis necessary to find out the vitality of the control circuits continuously.

Figure 272 shows an application of the trip circuit supervision function use. Thebest solution is to connect an external Rext shunt resistor in parallel with the circuitbreaker internal contact. Although the circuit breaker internal contact is open, TCScan see the trip circuit through Rext. The Rext resistor should have such a resistancethat the current through the resistance remains small, that is, it does not harm oroverload the circuit breaker's trip coil.

Section 6 1MRS756887 GSupervision functions


A051097 V4 EN

Figure 272: Operating principle of the trip-circuit supervision with an externalresistor. The TCSSCBR blocking switch is not required since theexternal resistor is used.

If TCS is required only in a closed position, the external shunt resistance can beomitted. When the circuit breaker is in the open position, TCS sees the situation asa faulty circuit. One way to avoid TCS operation in this situation would be to blockthe supervision function whenever the circuit breaker is open.

A051906 V2 EN

Figure 273: Operating principle of the trip-circuit supervision without anexternal resistor. The circuit breaker open indication is set to blockTCSSCBR when the circuit breaker is open.



Trip circuit supervision and other trip contactsIt is typical that the trip circuit contains more than one trip contact in parallel, forexample in transformer feeders where the trip of a Buchholz relay is connected inparallel with the feeder terminal and other relays involved. The supervising currentcannot detect if one or all the other contacts connected in parallel are not connectedproperly.

TCS

A070968 V3 EN

Figure 274: Constant test current flow in parallel trip contacts and trip circuitsupervision

In case of parallel trip contacts, the recommended way to do the wiring is that theTCS test current flows through all wires and joints.



A070970 V1 EN

Figure 275: Improved connection for parallel trip contacts where the testcurrent flows through all wires and joints

Several trip circuit supervision functions parallel in circuitNot only the trip circuit often have parallel trip contacts, it is also possible that thecircuit has multiple TCS circuits in parallel. Each TCS circuit causes its ownsupervising current to flow through the monitored coil and the actual coil current isa sum of all TCS currents. This must be taken into consideration when determiningthe resistance of Rext.

Setting the TCS function in a protection IED not-in-use does nottypically affect the supervising current injection.

Trip circuit supervision with auxiliary relaysMany retrofit projects are carried out partially, that is, the old electromechanicalrelays are replaced with new ones but the circuit breaker is not replaced. Thiscreates a problem that the coil current of an old type circuit breaker can be too highfor the protection IED trip contact to break.

The circuit breaker coil current is normally cut by an internal contact of the circuitbreaker. In case of a circuit breaker failure, there is a risk that the protection IEDtrip contact is destroyed since the contact is obliged to disconnect high level ofelectromagnetic energy accumulated in the trip coil.



An auxiliary relay can be used between the protection IED trip contact and thecircuit breaker coil. This way the breaking capacity question is solved, but the TCScircuit in the protection IED monitors the healthy auxiliary relay coil, not thecircuit breaker coil. The separate trip circuit supervision relay is applicable for thisto supervise the trip coil of the circuit breaker.

Dimensioning of the external resistorUnder normal operating conditions, the applied external voltage is divided betweenthe relay’s internal circuit and the external trip circuit so that at the minimum 20 V(15...20 V) remains over the relay’s internal circuit. Should the external circuit’sresistance be too high or the internal circuit’s too low, for example due to weldedrelay contacts, the fault is detected.

Mathematically, the operation condition can be expressed as:

U R R I V AC DCC ext int s c− + + × ≥(R ) /20


Uc Operating voltage over the supervised trip circuit

Ic Measuring current through the trip circuit, appr. 1.5 mA (0.99...1.72 mA)

Rext external shunt resistance

Rint internal shunt resistance, 1 kΩ

Rs trip coil resistance

If the external shunt resistance is used, it has to be calculated not to interfere withthe functionality of the supervision or the trip coil. Too high a resistance causes toohigh a voltage drop, jeopardizing the requirement of at least 20 V over the internalcircuit, while a resistance too low can enable false operations of the trip coil.

Table 452: Values recommended for the external resistor Rext

Operating voltage Uc Shunt resistor Rext

48 V DC 1.2 kΩ, 5 W

60 V DC 5.6 kΩ, 5 W

110 V DC 22 kΩ, 5 W

220 V DC 33 kΩ, 5 W

Due to the requirement that the voltage over the TCS contact must be 20V orhigher, the correct operation is not guaranteed with auxiliary operating voltageslower than 48V DC because of the voltage drop in Rint,Rext and the operating coilor even voltage drop of the feeding auxiliary voltage system which can cause toolow voltage values over the TCS contact. In this case, erroneous alarming can occur.

At lower (<48V DC) auxiliary circuit operating voltages, it is recommended to usethe circuit breaker position to block unintentional operation of TCS. The use of theposition indication is described earlier in this chapter.



Using power output contacts without trip circuit supervisionIf TCS is not used but the contact information of corresponding power outputs arerequired, the internal resistor can be by-passed. The output can then be utilized as anormal power output. When bypassing the internal resistor, the wiring between theterminals of the corresponding output X100:16-15(PO3) or X100:21-20(PO4) canbe disconnected. The internal resistor is required if the complete TCS circuit is used.

GUID-0560DE53-903C-4D81-BAFD-175B9251872D V1 EN

Figure 276: Connection of a power output in a case when TCS is not used andthe internal resistor is disconnected

Incorrect connections and use of trip circuit supervisionAlthough the TCS circuit consists of two separate contacts, it must be noted thatthose are designed to be used as series connected to guarantee the breakingcapacity given in the technical manual of the IED. In addition to the weak breakingcapacity, the internal resistor is not dimensioned to withstand current without aTCS circuit. As a result, this kind of incorrect connection causes immediateburning of the internal resistor when the circuit breaker is in the close position andthe voltage is applied to the trip circuit. The following picture shows incorrectusage of a TCS circuit when only one of the contacts is used.



A070972 V3 EN

Figure 277: Incorrect connection of trip-circuit supervision

A connection of three protection IEDs with a double pole trip circuit is shown inthe following figure. Only the IED R3 has an internal TCS circuit. In order to testthe operation of the IED R2, but not to trip the circuit breaker, the upper tripcontact of the IED R2 is disconnected, as shown in the figure, while the lowercontact is still connected. When the IED R2 operates, the coil current starts to flowthrough the internal resistor of the IED R3 and the resistor burns immediately. Asproven with the previous examples, both trip contacts must operate together.Attention should also be paid for correct usage of the trip-circuit supervision while,for example, testing the IED.



A070974 V3 EN

Figure 278: Incorrect testing of IEDs

6.1.6 SignalsTable 453: TCSSCBR Input signals

Name Type Default DescriptionBLOCK BOOLEAN 0=False Block signal for all binary outputs

Table 454: TCSSCBR Output signals

Name Type DescriptionALARM BOOLEAN Alarm output

6.1.7 SettingsTable 455: TCSSCBR Non group settings







6.1.8 Monitored dataTable 456: TCSSCBR Monitored data

Name Type Values (Range) Unit DescriptionTCSSCBR Enum 1=on


Status

6.2 Current circuit supervision CCRDIF




Current circuit supervision CCRDIF MCS 3I MCS 3I


GUID-7695BECB-3520-4932-9429-9A552171C0CA V1 EN


6.2.3 FunctionalityThe current circuit supervision function CCRDIF is used for monitoring currenttransformer secondary circuits.

CCRDIF calculates internally the sum of phase currents (I_A, I_B and I_C) andcompares the sum against the measured single reference current (I_REF). Thereference current must originate from other three-phase CT cores than the phasecurrents (I_A, I_B and I_C) and it is to be externally summated, that is, outside theIED.

CCRDIF detects a fault in the measurement circuit and issues an alarm or blocksthe protection functions to avoid unwanted tripping.

It must be remembered that the blocking of protection functions at an occurringopen CT circuit means that the situation remains unchanged and extremely highvoltages stress the secondary circuit.




The operation of current circuit supervision can be described by using a modulediagram. All the modules in the diagram are explained in the next sections.

GUID-A4F2DBEE-938F-4961-9DAD-977151DDBA13 V1 EN


Differential current monitoringDifferential current monitoring supervises the difference between the summedphase currents I_A, I_B and I_C and the reference current I_REF.

The current operating characteristics can be selected with the Start value setting.When the highest phase current is less than 1.0 xIn, the differential current limit isdefined with Start value. When the highest phase current is more than 1.0 xIn, thedifferential current limit is calculated with the formula:

MAX I A I B I C Startvalue( _ , _ , _ )×

GUID-A0C500CA-4A1A-44AA-AC14-4540676DD8CB V2 EN (Equation 65)

The differential current is limited to 1.0 xIn.



GUID-DC279F84-19B8-4FCB-A79A-2461C047F1B2 V1 EN

Figure 281: CCRDIF operating characteristics

When the differential current I_DIFF is in the operating region, the FAIL output isactivated.

The function is internally blocked if any phase current is higher than the set Maxoperate current. When the internal blocking activates, the FAIL output isdeactivated immediately. The internal blocking is used for avoiding false operationduring a fault situation when the current transformers are saturated due to highfault currents.

The value of the differential current is available in the monitored data view on theLHMI or through other communication tools. The value is calculated with theformula:

I DIFF I A I B I C I REF_ _ _ _ _= + + −

GUID-9CC931FA-0637-4FF8-85D4-6F461BD996A9 V2 EN (Equation 66)

The Start value setting is given in units of xIn of the phase current transformer. Thepossible difference in the phase and reference current transformer ratios isinternally compensated by scaling I_REF with the value derived from the Primarycurrent setting values. These setting parameters can be found in the Basic functionssection.

The activation of the BLOCK input deactivates the FAIL output immediately.



TimerThe timer is activated with the FAIL signal. The ALARM output is activated after afixed 200 ms delay. FAIL needs to be active during the delay.

When the internal blocking is activated, the FAIL output is deactivatedimmediately. The ALARM output is deactivated after a fixed 3 s delay, and theFAIL is deactivated.

The deactivation happens only when the highest phase current ismore than 5 percent of the nominal current (0.05 xIn).

When the line is de-energized, the deactivation of the ALARM output is prevented.

The activation of the BLOCK input deactivates the ALARM output.

6.2.5 ApplicationOpen or short-circuited current transformer cores can cause unwanted operation inmany protection functions such as differential, earth-fault current and negative-sequence current functions. When currents from two independent three-phase setsof CTs or CT cores measuring the same primary currents are available, reliablecurrent circuit supervision can be arranged by comparing the currents from the twosets. When an error in any CT circuit is detected, the protection functionsconcerned can be blocked and an alarm given.

In case of high currents, the unequal transient saturation of CT cores with adifferent remanence or saturation factor can result in differences in the secondarycurrents from the two CT cores. An unwanted blocking of protection functionsduring the transient stage must then be avoided.

The supervision function must be sensitive and have a short operation time toprevent unwanted tripping from fast-acting, sensitive numerical protections in caseof faulty CT secondary circuits.

Open CT circuits create extremely high voltages in the circuits,which may damage the insulation and cause further problems. Thismust be taken into consideration especially when the protectionfunctions are blocked.

When the reference current is not connected to the IED, thefunction should be turned off. Otherwise, the FAIL output isactivated when unbalance occurs in the phase currents even if therewas nothing wrong with the measurement circuit.



Reference current measured with core-balanced current transformerCCRDIF compares the sum of phase currents to the current measured with the core-balanced CT.

GUID-88FC46C8-8D14-45DE-9E36-E517EA3886AA V1 EN

Figure 282: Connection diagram for reference current measurement with core-balanced current transformer

Current measurement with two independent three-phase sets of CTcoresFigure 283 and Figure 284 show diagrams of connections where the referencecurrent is measured with two independent three-phase sets of CT cores.



GUID-8DC3B17A-13FE-4E38-85C6-A228BC03206B V1 EN

Figure 283: Connection diagram for current circuit supervision with two sets ofthree-phase current transformer protection cores

When using the measurement core for reference currentmeasurement, it should be noted that the saturation level of themeasurement core is much lower than with the protection core. Thisshould be taken into account when setting the current circuitsupervision function.



GUID-C5A6BB27-36F9-4652-A5E4-E3D32CFEA77B V1 EN

Figure 284: Connection diagram for current circuit supervision with two sets ofthree-phase current transformer cores (protection andmeasurement)

Example of incorrect connectionThe currents must be measured with two independent cores, that is, the phasecurrents must be measured with a different core than the reference current. Aconnection diagram shows an example of a case where the phase currents and thereference currents are measured from the same core.



GUID-BBF3E23F-7CE4-43A3-8986-5AACA0433235 V1 EN

Figure 285: Example of incorrect reference current connection

6.2.6 SignalsTable 457: CCRDIF Input signals




I_REF SIGNAL 0 Reference current


Table 458: CCRDIF Output signals

Name Type DescriptionFAIL BOOLEAN Fail output

ALARM BOOLEAN Alarm output



6.2.7 SettingsTable 459: CCRDIF Non group settings


5=off 1=on Operation On / Off

Start value 0.05...0.20 xIn 0.01 0.05 Minimum operate current differential level

Max operate current 1.00...5.00 xIn 0.01 1.50 Block of the function at high phase current

6.2.8 Monitored dataTable 460: CCRDIF Monitored data

Name Type Values (Range) Unit DescriptionIDIFF FLOAT32 0.00...40.00 xIn Differential current

CCRDIF Enum 1=on2=blocked3=test4=test/blocked5=off

Status

6.2.9 Technical dataTable 461: CCRDIF Technical data

Characteristic ValueOperate time1) < 30 ms

1) Including the delay of the output contact

6.3 Protection communication supervision PCSRTPC




Protection communication supervision PCSRTPC PCS PCS




GUID-8732CEA2-358D-441A-B5BB-B2DC9E36E4A4 V1 EN


6.3.3 FunctionalityThe protection communication supervision function PCSRTPC monitors theprotection communication channel. PCSRTPC blocks the line differentialprotection functions when interference in the protection communication channel isdetected. The blocking takes place automatically for the LNPLDF and BSTGGIOfunctions which are dependent on the continuous availability of the protectioncommunication channel.

The protection communication channel is continuously monitored by PCSRTPC.The function detects missing or delayed protection telegrams. Protection telegramsare used for transferring the sampled analog and other protection related data.Missing or delayed protection telegrams can jeopardize the demand operate speedof the differential protection.

When a short-term interference is detected in the protection communicationchannel, the function issues a warning and the line differential functions areautomatically internally blocked. PCSRTPC reacts fast for the protectioncommunication interferences. The blocking takes place at the latest when acommunication interruption lasting for two fundamental network periods isdetected. When a severe and long lasting interference or total interruption in theprotection communication channel is detected, an alarm is issued (after a five-second delay). The protection communication supervision quality status isexchanged continuously online by the local and remote PCSRTPC instances. Thisensures that both local and remote ends protection blocking is issued coordinately.This further enhances the security of the line differential protection by forcing bothline end IEDs to the same blocking state during a protection communicationinterference, even in cases where the interference is detected with only one line endIED. There is also the Reset delay time settings parameter available which is usedfor changing the required interference-free time before releasing the line-differential protection back in operation after a blocking due to an interference incommunication.



6.3.4 Operation principleThe operation of protection communication supervision can be described by usinga module diagram. All the modules in the diagram are explained in the next sections.

GUID-FE089DD8-D0A0-4D3B-9287-48B11ADBAC25 V1 EN


Communication supervisionThe protection communication is supervised because the differential calculation isdependent on the refreshing of new analog phasor samples from the remoteterminal within the protection telegram. The new protection telegram also updatesthe status of the binary signals sent by the remote terminal. The calculation of thedifferential current is based on comparing the remote and local terminal measuredcurrent samples. It is therefore essential that the protection communicationtelegrams are supervised and the result of the sample latency calculation can beused further in the differential current calculation. When the communication is ableto receive telegrams correctly from the remote end via the communication media,the communication is assumed to be operating correctly and the COMM output iskept active.

Communication interference detectorThe communication interference detector is continuously measuring and observingthe sample latency of the protection telegrams. This value is also available asmonitored data. The function provides three output signals of which only thecorresponding one is active at a time depending on if the protection communicationsupervision is in OK, WARNING or ALARM. The OK state indicates the correctoperation of the protection. The WARNING state indicates that the protection isinternally blocked due to detected interference. The WARNING state is switched toALARM if the interference lasts for a longer period. The protection communicationsupervision can sometimes be in the WAITING state. This state indicates that theterminal is waiting for the communication to start or restart from the remote endterminal.

TimerOnce activated with the WARNING signal, the timer has a constant time delay valueof five seconds. If the communication failure exists after the delay, the ALARMoutput is activated.



6.3.5 Application

Communication principleAnalog samples, trip-, start- and user programmable signals are transferred in eachprotection telegram and the exchange of these protection telegrams is done eighttimes per power system cycle (every 2.5 ms when Fn = 50 Hz).

Master-Master communication arrangement is used in the two-terminal linedifferential solution. Current samples are sent from both line ends and theprotection algorithms are also executed on both line ends. The direct-intertrip,however, ensures that both ends are always operated simultaneously.

Time synchronizationIn numerical line differential protection, the current samples from the protectionswhich are located geographically apart from each other must be time coordinatedso that the current samples from both ends of the protected line can be comparedwithout introducing irrelevant errors. The time coordination requires an extremelyhigh accuracy.

As an example, an inaccuracy of 0.1 ms in a 50 Hz system gives a maximumamplitude error of approximately around 3 percent. An inaccuracy of 1 ms gives amaximum amplitude error of approximately 31 percent. The corresponding figuresfor a 60 Hz system are 4 and 38 percent respectively.

In the IED, the time coordination is done with an echo method. The IEDs createtheir own time reference between each other so that the system clocks do not needto synchronize.

The figure shows that in the time synchronization the transmission time to send amessage from station B to station A, T1→T2, and the time to receive a messagefrom A to B, T4→T5, are measured. The station A IED delay from the sampling tothe start of send, T3→T4, and the local delay from receive to the station B IEDsampling T5→T6 time, are also measured for the station B IED, and vice versa.This way the time alignment factor for the local and remote samples is achieved.

GUID-2DDF64E2-D635-4783-854A-A62E5EFB7186 V1 EN

Figure 288: Measuring sampling latency

PT T T T

d =− + −( ) ( )2 1 5 4

2

GUID-0CB3B365-7081-43D4-90F5-91A8082522FE V2 EN (Equation 67)



S P T T T Td d= + − + −( ) ( )4 3 6 5

GUID-2940B36E-3A6C-44E4-BD39-1B117E168829 V2 EN (Equation 68)

The sampling latency Sd is calculated for each telegram on both ends. Thealgorithm assumes that the one-way propagation delay Pd is equal for both directions.

The echo method without GPS can be used in telecommunication transmissionnetworks as long as delay symmetry exists, that is, the sending and receivingdelays are equal.

6.3.6 SignalsTable 462: PCSRTPC Output signals

Name Type DescriptionOK BOOLEAN Protection communication ok

WARNING BOOLEAN Protection communication warning

ALARM BOOLEAN Protection communication alarm

COMM BOOLEAN Communication detected, active when data isreceived

6.3.7 SettingsTable 463: PCSRTPC Non group settings

Parameter Values (Range) Unit Step Default DescriptionReset delay time 100...300000 ms 10 1000 Reset delay time from alarm and

warning into ok state

Alarm count 0...99999 0 Set new alarm count value

Warning count 0...99999 0 Set new warning count value

6.3.8 Monitored dataTable 464: PCSRTPC Monitored data

Name Type Values (Range) Unit DescriptionHEALTH Enum 1=Ok

2=Warning3=Alarm-2=Waiting

Communication linkhealth

ALARM_CNT INT32 0...99999 Number of alarmsdetected

WARN_CNT INT32 0...99999 Number of warningsdetected

SMPL_LATENCY FLOAT32 0.000...99.999 ms Measured samplelatency

PROPAGTN_DLY FLOAT32 0.000...99.999 ms Measured propagationdelay




Name Type Values (Range) Unit DescriptionRND_TRIP_DLY FLOAT32 0.000...99.999 ms Measured round trip

delay

T_ALARM_CNT Timestamp Time when alarm countwas last changed

T_WARN_CNT Timestamp Time when warningcount was last changed

6.3.9 Technical revision historyTable 465: PCSTRPC Technical revision history

Technical revision ChangeB Changes and additions to the monitored data

6.4 Fuse failure supervision SEQRFUF




Fuse failure supervision SEQRFUF FUSEF 60


GUID-0A336F51-D8FA-4C64-A7FE-7A4270E621E7 V1 EN


6.4.3 FunctionalityThe fuse failure supervision function SEQRFUF is used to block the voltage-measuring functions at failures in the secondary circuits between the voltagetransformer and IED to avoid misoperations of the voltage protection functions.



SEQRFUF has two algorithms, a negative sequence-based algorithm and a deltacurrent and delta voltage algorithm.

A criterion based on the delta current and the delta voltage measurements can beactivated to detect three-phase fuse failures which usually are more associated withthe voltage transformer switching during station operations.


The operation of the fuse failure supervision function can be described with amodule diagram. All the modules in the diagram are explained in the next sections.

GUID-27E5A90A-6DCB-4545-A33A-F37C02F27A28 V1 EN


Negative phase-sequence criterionA fuse failure based on the negative-sequence criterion is detected if the measurednegative-sequence voltage exceeds the set Neg Seq voltage Lev value and themeasured negative-sequence current is below the set Neg Seq current Lev value.The detected fuse failure is reported to the decision logic module.

Voltage checkThe phase voltage magnitude is checked when deciding whether the fuse failure isa three, two or a single-phase fault.



The module makes a phase-specific comparison between each voltage input andthe Seal in voltage setting. If the input voltage is lower than the setting, thecorresponding phase is reported to the decision logic module.

Current and voltage delta criterionThe delta function can be activated by setting the Change rate enable parameter to"True". Once the function is activated, it operates in parallel with the negativesequence-based algorithm. The current and voltage are continuously measured inall three phases to calculate:

• Change of voltage dU/dt• Change of current dI/dt

The calculated delta quantities are compared to the respective set values of theCurrent change rate and Voltage change rate settings.

The delta current and delta voltage algorithms detect a fuse failure if there is asufficient negative change in the voltage amplitude without a sufficient change inthe current amplitude in each phase separately. This is performed when the circuitbreaker is closed. Information about the circuit breaker position is connected to theCB_CLOSED input.

There are two conditions for activating the current and voltage delta function.

• The magnitude of dU/dt exceeds the corresponding value of the Voltagechange rate setting and magnitude of dI/dt is below the value of the Currentchange rate setting in any phase at the same time due to the closure of thecircuit breaker (CB_CLOSED = TRUE).

• The magnitude of dU/dt exceeds the value of the Voltage change rate settingand the magnitude of dI/dt is below the Current change rate setting in anyphase at the same time and the magnitude of the phase current in the samephase exceeds the Min Op current delta setting.

The first condition requires the delta criterion to be fulfilled in any phase at thesame time as the circuit breaker is closed. Opening the circuit breaker at one endand energizing the line from the other end onto a fault could lead to an improperoperation of SEQRFUF with an open breaker. If this is considered to be animportant disadvantage, the CB_CLOSED input is to be connected to FALSE. Inthis way only the second criterion can activate the delta function.

The second condition requires the delta criterion to be fulfilled in one phasetogether with a high current for the same phase. The measured phase current isused to reduce the risk of a false fuse failure detection. If the current on theprotected line is low, a voltage drop in the system (not caused by the fuse failure) isnot followed by a current change and a false fuse failure can occur. To prevent this,the minimum phase current criterion is checked.

The fuse failure detection is active until the voltages return above the Min Opvoltage delta setting. If a voltage in a phase is below the Min Op voltage delta



setting, a new fuse failure detection for that phase is not possible until the voltagereturns above the setting value.

Decision logicThe fuse failure detection outputs FUSEF_U and FUSEF_3PH are controlledaccording to the detection criteria or external signals.

Table 466: Fuse failure output control

Fuse failure detection criterion Conditions and function responseNegative-sequence criterion If a fuse failure is detected based on the

negative sequence criterion, the FUSEF_U outputis activated.

If the fuse failure detection is active for morethan five seconds and at the same time all thephase voltage values are below the set value ofthe Seal in voltage setting with Enable seal inturned to "True", the function activates theFUSE_3PH output signal.

The FUSEF_U output signal is also activated if allthe phase voltages are above the Seal in voltagesetting for more than 60 seconds and at thesame time the negative sequence voltage isabove Neg Seq voltage Lev for more than 5seconds, all the phase currents are below theCurrent dead Lin Val setting and the circuitbreaker is closed, that is,CB_CLOSED is TRUE.

Current and voltage delta function criterion If the current and voltage delta criterion detects afuse failure condition, but all the voltages are notbelow the Seal in voltage setting, only theFUSEF_U output is activated.

If the fuse failure detection is active for morethan five seconds and at the same time all thephase voltage values are below the set value ofthe Seal in voltage setting with Enable seal inturned to "True", the function activates theFUSE_3PH output signal.

External fuse failure detection The MINCB_OPEN input signal is supposed to beconnected through an IED binary input to theN.C. auxiliary contact of the miniature circuitbreaker protecting the VT secondary circuit.TheMINCB_OPEN signal sets the FUSEF_U outputsignal to block all the voltage-related functionswhen MCB is in the open state.

The DISCON_OPEN input signal is supposed tobe connected through an IED binary input to theN.C. auxiliary contact of the line disconnector. TheDISCON_OPEN signal sets the FUSEF_U outputsignal to block the voltage-related functionswhen the line disconnector is in the open state.

It is recommended to always set Enable seal in to "True". Thissecures that the blocked protection functions remain blocked untilnormal voltage conditions are restored if the fuse failure has been



active for 5 seconds, that is, the fuse failure outputs are deactivatedwhen the normal voltage conditions are restored.

The activation of the BLOCK input deactivates both FUSEF_U and FUSEF_3PHoutputs.

6.4.5 ApplicationSome protection functions operate on the basis of the measured voltage value in theIED point. These functions can fail if there is a fault in the measuring circuitsbetween the voltage transformers and the IED.

A fault in the voltage-measuring circuit is referred to as a fuse failure. This term ismisleading since a blown fuse is just one of the many possible reasons for a brokencircuit. Since incorrectly measured voltage can result in a faulty operation of someof the protection functions, it is important to detect the fuse failures. A fast fusefailure detection is one of the means to block voltage-based functions before theyoperate.

GUID-FA649B6A-B51E-47E2-8E37-EBA9CDEB2BF5 V1 EN

Figure 291: Fault in a circuit from the voltage transformer to the IED

A fuse failure occurs due to blown fuses, broken wires or intended substationoperations. The negative sequence component-based function can be used to detectdifferent types of single-phase or two-phase fuse failures. However, at least one ofthe three circuits from the voltage transformers must not be broken. The supportingdelta-based function can also detect a fuse failure due to three-phase interruptions.

In the negative sequence component-based part of the function, a fuse failure isdetected by comparing the calculated value of the negative sequence componentvoltage to the negative sequence component current. The sequence entities arecalculated from the measured current and voltage data for all three phases. Thepurpose of this function is to block voltage-dependent functions when a fuse failure



is detected. Since the voltage dependence differs between these functions,SEQRFUF has two outputs for this purpose.

6.4.6 SignalsTable 467: SEQRFUF Input signals





U_A_AB SIGNAL 0 Phase A voltage

U_B_BC SIGNAL 0 Phase B voltage

U_C_CA SIGNAL 0 Phase C voltage


BLOCK BOOLEAN 0=False Block of function

CB_CLOSED BOOLEAN 0=False Active when circuit breaker is closed

DISCON_OPEN BOOLEAN 0=False Active when line disconnector is open

MINCB_OPEN BOOLEAN 0=False Active when external MCB opens protectedvoltage circuit

Table 468: SEQRFUF Output signals

Name Type DescriptionFUSEF_3PH BOOLEAN Three-phase start of function

FUSEF_U BOOLEAN General start of function

6.4.7 SettingsTable 469: SEQRFUF Non group settings



Neg Seq current Lev 0.03...0.20 xIn 0.01 0.03 Operate level of neg seq undercurrentelement

Neg Seq voltage Lev 0.03...0.20 xUn 0.01 0.10 Operate level of neg seq overvoltageelement

Current change rate 0.01...0.50 xIn 0.01 0.15 Operate level of change in phase current

Voltage change rate 0.50...0.90 xUn 0.01 0.60 Operate level of change in phase voltage

Change rate enable 0=False1=True

0=False Enabling operation of change basedfunction

Min Op voltage delta 0.01...1.00 xUn 0.01 0.70 Minimum operate level of phase voltagefor delta calculation




Parameter Values (Range) Unit Step Default DescriptionMin Op current delta 0.01...1.00 xIn 0.01 0.10 Minimum operate level of phase current

for delta calculation

Seal in voltage 0.01...1.00 xUn 0.01 0.70 Operate level of seal-in phase voltage

Enable seal in 0=False1=True

0=False Enabling seal in functionality

Current dead Lin Val 0.05...1.00 xIn 0.01 0.05 Operate level for open phase currentdetection

6.4.8 Monitored dataTable 470: SEQRFUF Monitored data

Name Type Values (Range) Unit DescriptionSEQRFUF Enum 1=on


Status

6.4.9 Technical dataTable 471: SEQRFUF Technical data

Characteristic ValueOperate time1)

• NPS function UFault = 1.1 x set NegSeq voltage Lev

< 33 ms

UFault = 5.0 x set NegSeq voltage Lev

< 18 ms

• Delta function ΔU = 1.1 x set Voltagechange rate

< 30 ms

ΔU = 2.0 x set Voltagechange rate

< 24 ms

1) Includes the delay of the signal output contact, fn = 50 Hz, fault voltage with nominal frequencyinjected from random phase angle, results based on statistical distribution of 1000 measurements

6.5 Operation time counter MDSOPT




Runtime counter for machines anddevices

MDSOPT OPTS OPTM




GUID-C20AF735-FF25-411B-9EA6-11D595484613 V3 EN


6.5.3 FunctionalityThe generic runtime counter function MDSOPT calculates and presents theaccumulated operation time of a machine or device as the output. The unit of timefor accumulation is hour. The function generates a warning and an alarm when theaccumulated operation time exceeds the set limits. It utilizes a binary input toindicate the active operation condition.

The accumulated operation time is one of the parameters for scheduling a serviceon the equipment like motors. It indicates the use of the machine and hence themechanical wear and tear. Generally, the equipment manufacturers provide amaintenance schedule based on the number of hours of service.


The operation of the generic runtime counter for machines and devices can bedescribed using a module diagram. All the modules in the diagram are explained inthe next sections.

GUID-6BE6D1E3-F3FB-45D9-8D6F-A44752C1477C V1 EN


Operation time counterThis module counts the operation time. When POS_ACTIVE is active, the count iscontinuously added to the time duration until it is deactivated. At any time theOPR_TIME output is the total duration for which POS_ACTIVE is active. The unitof time duration count for OPR_TIME is hour. The value is available through theMonitored data view.

The OPR_TIME output is a continuously increasing value and it is stored in a non-volatile memory. When POS_ACTIVE is active, the OPR_TIME count starts



increasing from the previous value. The count of OPR_TIME saturates at the finalvalue of 299999, that is, no further increment is possible. The activation of RESETcan reset the count to the Initial value setting.

Limit SupervisionThis module compares the motor run-time count to the set values of Warning valueand Alarm value to generate the WARNING and ALARM outputs respectively whenthe counts exceed the levels.

The activation of the WARNING and ALARM outputs depends on the Operating timemode setting. Both WARNING and ALARM occur immediately after the conditionsare met if Operating time mode is set to “Immediate”. If Operating time mode is setto “Timed Warn”, WARNING is activated within the next 24 hours at the time of theday set using the Operating time hour setting. If Operating time mode is set to“Timed Warn Alm”, the WARNING and ALARM outputs are activated at the time ofday set using Operating time hour.

The Operating time hour setting is used to set the hour of day inCoordinated Universal Time (UTC). The setting has to be adjustedaccording to the local time and local daylight-saving time.

The function contains a blocking functionality. Activation of the BLOCK inputblocks both WARNING and ALARM.

6.5.5 ApplicationThe machine operating time since commissioning indicates the use of the machine.For example, the mechanical wear and lubrication requirement for the shaft bearingof the motors depend on the use hours.

If some motor is used for long duration runs, it might require frequent servicing,while for a motor that is not used regularly the maintenance and service arescheduled less frequently. The accumulated operating time of a motor together withthe appropriate settings for warning can be utilized to trigger the condition basedmaintenance of the motor.

The operating time counter combined with the subsequent reset of the operating-time count can be used to monitor the motor's run time for a single run.

Both the long term accumulated operating time and the short term single runduration provide valuable information about the condition of the machine anddevice. The information can be co-related to other process data to providediagnoses for the process where the machine or device is applied.



6.5.6 SignalsTable 472: MDSOPT Input signals

Name Type Default DescriptionBLOCK BOOLEAN 0=False Block input status

POS_ACTIVE BOOLEAN 0=False When active indicates the equipment is running

RESET BOOLEAN 0=False Resets the accumulated operation time to initialvalue

Table 473: MDSOPT Output signals

Name Type DescriptionALARM BOOLEAN Alarm accumulated operation time exceeds Alarm

value

WARNING BOOLEAN Warning accumulated operation time exceedsWarning value

6.5.7 SettingsTable 474: MDSOPT Non group settings



Warning value 0...299999 h 1 8000 Warning value for operation timesupervision

Alarm value 0...299999 h 1 10000 Alarm value for operation time supervision

Initial value 0...299999 h 1 0 Initial value for operation time supervision

Operating time hour 0...23 h 1 0 Time of day when alarm and warning willoccur

Operating time mode 1=Immediate2=Timed Warn3=Timed Warn Alm

1=Immediate Operating time mode for warning andalarm

6.5.8 Monitored dataTable 475: MDSOPT Monitored data

Name Type Values (Range) Unit DescriptionMDSOPT Enum 1=on


Status

OPR_TIME INT32 0...299999 h Total operation time inhours



6.5.9 Technical dataTable 476: MDSOPT Technical data

Description ValueMotor run-time measurement accuracy1) ±0.5%

1) Of the reading, for a stand-alone IED, without time synchronization.



Section 7 Condition monitoring functions

7.1 Circuit breaker condition monitoring SSCBR




Circuit breaker condition monitoring SSCBR CBCM CBCM


A070795 V2 EN


7.1.3 FunctionalityThe circuit breaker condition monitoring function SSCBR is used to monitordifferent parameters of the circuit breaker. The breaker requires maintenance whenthe number of operations has reached a predefined value. The energy is calculatedfrom the measured input currents as a sum of Iyt values. Alarms are generatedwhen the calculated values exceed the threshold settings.

The function contains a blocking functionality. It is possible to block the functionoutputs, if desired.

1MRS756887 G Section 7Condition monitoring functions


7.1.4 Operation principleThe circuit breaker condition monitoring function includes different metering andmonitoring subfunctions. The functions can be enabled and disabled with theOperation setting. The corresponding parameter values are “On” and “Off”. Theoperation counters are cleared when Operation is set to “Off”.

The operation of the functions can be described with a module diagram. All themodules in the diagram are explained in the next sections.

A071103 V3 EN


Section 7 1MRS756887 GCondition monitoring functions


7.1.4.1 Circuit breaker status

The circuit breaker status subfunction monitors the position of the circuit breaker,that is, whether the breaker is in an open, closed or intermediate position. Theoperation of the breaker status monitoring can be described by using a modulediagram. All the modules in the diagram are explained in the next sections.

A071104 V3 EN

Figure 296: Functional module diagram for monitoring circuit breaker status

Phase current checkThis module compares the three phase currents to the setting Acc stop current. Ifthe current in a phase exceeds the set level, information about the phase is reportedto the contact position indicator module.

Contact position indicatorThe circuit breaker status is open if the auxiliary input contact POSCLOSE is low,the POSOPEN input is high and the current is zero. The circuit breaker is closedwhen the POSOPEN input is low and the POSCLOSE input is high. The breaker isin the intermediate position if both the auxiliary contacts have the same value, thatis, both are in the logical level "0", or if the auxiliary input contact POSCLOSE islow and the POSOPEN input is high, but the current is not zero.

The status of the breaker is indicated with the binary outputs OPENPOS,INTERMPOS and CLOSEPOS for open, intermediate and closed positionrespectively.

7.1.4.2 Circuit breaker operation monitoring

The purpose of the circuit breaker operation monitoring subfunction is to indicate ifthe circuit breaker has not been operated for a long time.

The operation of the circuit breaker operation monitoring can be described with amodule diagram. All the modules in the diagram are explained in the next sections.



A071105 V2 EN

Figure 297: Functional module diagram for calculating inactive days and alarmfor circuit breaker operation monitoring

Inactivity timerThe module calculates the number of days the circuit breaker has remainedinactive, that is, has stayed in the same open or closed state. The calculation is doneby monitoring the states of the POSOPEN and POSCLOSE auxiliary contacts.

The inactive days INA_DAYS is available in the monitored data view. It is alsopossible to set the initial inactive days with the Ini inactive days parameter.

Alarm limit checkWhen the inactive days exceed the limit value defined with the Inactive Alm dayssetting, the MON_ALM alarm is initiated. The time in hours at which this alarm isactivated can be set with the Inactive Alm hours parameter as coordinates of UTC.The alarm signal MON_ALM can be blocked by activating the binary input BLOCK.

7.1.4.3 Breaker contact travel time

The breaker contact travel time module calculates the breaker contact travel timefor the closing and opening operation. The operation of the breaker contact traveltime measurement can be described with a module diagram. All the modules in thediagram are explained in the next sections.

A071106 V3 EN

Figure 298: Functional module diagram for breaker contact travel time

Traveling time calculatorThe contact travel time of the breaker is calculated from the time between auxiliarycontacts' state change. The open travel time is measured between the opening ofthe POSCLOSE auxiliary contact and the closing of the POSOPEN auxiliarycontact. Travel time is also measured between the opening of the POSOPENauxiliary contact and the closing of the POSCLOSE auxiliary contact.



A071107 V1 EN

Figure 299: Travel time calculation

There is a time difference t1 between the start of the main contact opening and theopening of the POSCLOSE auxiliary contact. Similarly, there is a time gap t2between the time when the POSOPEN auxiliary contact opens and the main contactis completely open. Therefore, to incorporate the time t1+t2, a correction factorneeds to be added with topen to get the actual opening time. This factor is addedwith the Opening time Cor (=t1+t2) setting. The closing time is calculated byadding the value set with the Closing time Cor (t3+t4) setting to the measuredclosing time.

The last measured opening travel time T_TRV_OP and the closing travel timeT_TRV_CL are available in the monitored data view on the LHMI or through toolsvia communications.

Alarm limit checkWhen the measured opening travel time is longer than the value set with the Openalarm time setting, the TRV_T_OP_ALM output is activated. Respectively, whenthe measured closing travel time is longer than the value set with the Close alarmtime setting, the TRV_T_CL_ALM output is activated.

It is also possible to block the TRV_T_CL_ALM and TRV_T_OP_ALM alarmsignals by activating the BLOCK input.

7.1.4.4 Operation counter

The operation counter subfunction calculates the number of breaker operationcycles. The opening and closing operations are both included in one operationcycle. The operation counter value is updated after each opening operation.

The operation of the subfunction can be described with a module diagram. All themodules in the diagram are explained in the next sections.



A071108 V2 EN

Figure 300: Functional module diagram for counting circuit breaker operations

Operation counterThe operation counter counts the number of operations based on the state change ofthe binary auxiliary contacts inputs POSCLOSE and POSOPEN.

The number of operations NO_OPR is available in the monitored data view on theLHMI or through tools via communications. The old circuit breaker operationcounter value can be taken into use by writing the value to the Counter initial Valparameter and by setting the parameter CB wear values in the clear menu fromWHMI or LHMI.

Alarm limit checkThe OPR_ALM operation alarm is generated when the number of operationsexceeds the value set with the Alarm Op number threshold setting. However, if thenumber of operations increases further and exceeds the limit value set with theLockout Op number setting, the OPR_LO output is activated.

The binary outputs OPR_LO and OPR_ALM are deactivated when the BLOCK inputis activated.

7.1.4.5 Accumulation of Iyt

Accumulation of the Iyt module calculates the accumulated energy.

The operation of the module can be described with a module diagram. All themodules in the diagram are explained in the next sections.

A071109 V2 EN

Figure 301: Functional module diagram for calculating accumulative energyand alarm



Accumulated energy calculator

This module calculates the accumulated energy Iyt [(kA)ys]. The factor y is set withthe Current exponent setting.

The calculation is initiated with the POSCLOSE input opening events. It ends whenthe RMS current becomes lower than the Acc stop current setting value.

A071110 V1 EN

Figure 302: Significance of the Difference Cor time setting

The Difference Cor time setting is used instead of the auxiliary contact toaccumulate the energy from the time the main contact opens. If the setting ispositive, the calculation of energy starts after the auxiliary contact has opened andwhen the delay is equal to the value set with the Difference Cor time setting. Whenthe setting is negative, the calculation starts in advance by the correction timebefore the auxiliary contact opens.

The accumulated energy outputs IPOW_A (_B, _C) are available in themonitored data view on the LHMI or through tools via communications. Thevalues can be reset by setting the parameter CB accum. currents power setting totrue in the clear menu from WHMI or LHMI.

Alarm limit checkThe IPOW_ALM alarm is activated when the accumulated energy exceeds the valueset with the Alm Acc currents Pwr threshold setting. However, when the energyexceeds the limit value set with the LO Acc currents Pwr threshold setting, theIPOW_LO output is activated.

The IPOW_ALM and IPOW_LO outputs can be blocked by activating the binaryinput BLOCK.

7.1.4.6 Remaining life of circuit breaker

Every time the breaker operates, the life of the circuit breaker reduces due towearing. The wearing in the breaker depends on the tripping current, and theremaining life of the breaker is estimated from the circuit breaker trip curve



provided by the manufacturer. The remaining life is decremented at least with onewhen the circuit breaker is opened.

The operation of the remaining life of the circuit breaker subfunction can bedescribed with a module diagram. All the modules in the diagram are explained inthe next sections.

A071111 V2 EN

Figure 303: Functional module diagram for estimating the life of the circuitbreaker

Circuit breaker life estimatorThe circuit breaker life estimator module calculates the remaining life of the circuitbreaker. If the tripping current is less than the rated operating current set with theRated Op current setting, the remaining operation of the breaker reduces by oneoperation. If the tripping current is more than the rated fault current set with theRated fault current setting, the possible operations are zero. The remaining life ofthe tripping current in between these two values is calculated based on the tripcurve given by the manufacturer. The Op number rated and Op number faultparameters set the number of operations the breaker can perform at the ratedcurrent and at the rated fault current, respectively.

The remaining life is calculated separately for all three phases and it is available asa monitored data value CB_LIFE_A (_B,_C). The values can be cleared bysetting the parameter CB wear values in the clear menu from WHMI or LHMI.

Clearing CB wear values also resets the operation counter.

Alarm limit checkWhen the remaining life of any phase drops below the Life alarm level thresholdsetting, the corresponding circuit breaker life alarm CB_LIFE_ALM is activated.

It is possible to deactivate the CB_LIFE_ALM alarm signal by activating thebinary input BLOCK. The old circuit breaker operation counter value can be takeninto use by writing the value to the Initial CB Rmn life parameter and resetting thevalue via the clear menu from WHMI or LHMI.



7.1.4.7 Circuit breaker spring-charged indication

The circuit breaker spring-charged indication subfunction calculates the springcharging time.


A071112 V3 EN

Figure 304: Functional module diagram for circuit breaker spring-chargedindication and alarm

Spring charge time measurementTwo binary inputs, SPR_CHR_ST and SPR_CHR, indicate spring charging startedand spring charged, respectively. The spring-charging time is calculated from thedifference of these two signal timings.

The spring charging time T_SPR_CHR is available in the monitored data view onthe LHMI or through tools via communications.

Alarm limit checkIf the time taken by the spring to charge is more than the value set with the Springcharge time setting, the subfunction generates the SPR_CHR_ALM alarm.

It is possible to block the SPR_CHR_ALM alarm signal by activating the BLOCKbinary input.

7.1.4.8 Gas pressure supervision

The gas pressure supervision subfunction monitors the gas pressure inside the arcchamber.




A071113 V2 EN

Figure 305: Functional module diagram for circuit breaker gas pressure alarm

The gas pressure is monitored through the binary input signals PRES_LO_IN andPRES_ALM_IN.

Timer 1When the PRES_ALM_IN binary input is activated, the PRES_ALM alarm isactivated after a time delay set with the Pressure alarm time setting. ThePRES_ALM alarm can be blocked by activating the BLOCK input.

Timer 2If the pressure drops further to a very low level, the PRES_LO_IN binary inputbecomes high, activating the lockout alarm PRES_LO after a time delay set withthe Pres lockout time setting. The PRES_LO alarm can be blocked by activatingthe BLOCK input.

7.1.5 ApplicationSSCBR includes different metering and monitoring subfunctions.

Circuit breaker statusCircuit breaker status monitors the position of the circuit breaker, that is, whetherthe breaker is in an open, closed or intermediate position.

Circuit breaker operation monitoringThe purpose of the circuit breaker operation monitoring is to indicate that thecircuit breaker has not been operated for a long time. The function calculates thenumber of days the circuit breaker has remained inactive, that is, has stayed in thesame open or closed state. There is also the possibility to set an initial inactive day.

Breaker contact travel timeHigh traveling times indicate the need for the maintenance of the circuit breakermechanism. Therefore, detecting excessive traveling time is needed. During theopening cycle operation, the main contact starts opening. The auxiliary contact Aopens, the auxiliary contact B closes and the main contact reaches its openingposition. During the closing cycle, the first main contact starts closing. Theauxiliary contact B opens, the auxiliary contact A closes and the main contact



reaches its closed position. The travel times are calculated based on the statechanges of the auxiliary contacts and the adding correction factor to consider thetime difference of the main contact's and the auxiliary contact's position change.

Operation counterRoutine maintenance of the breaker, such as lubricating breaker mechanism, isgenerally based on a number of operations. A suitable threshold setting to raise analarm when the number of operation cycle exceeds the set limit helps preventivemaintenance. This can also be used to indicate the requirement for oil sampling fordielectric testing in case of an oil circuit breaker.

The change of state can be detected from the binary input of the auxiliary contact.There is a possibility to set an initial value for the counter which can be used toinitialize this functionality after a period of operation or in case of refurbishedprimary equipment.

Accumulation of Iyt

Accumulation of Iyt calculates the accumulated energy ΣIyt, where the factor y isknown as the current exponent. The factor y depends on the type of the circuitbreaker. For oil circuit breakers, the factor y is normally 2. In case of a high-voltage system, the factor y can be 1.4...1.5.

Remaining life of the breakerEvery time the breaker operates, the life of the circuit breaker reduces due towearing. The wearing in the breaker depends on the tripping current, and theremaining life of the breaker is estimated from the circuit breaker trip curveprovided by the manufacturer.

Example for estimating the remaining life of a circuit breaker



A071114 V3 EN

Figure 306: Trip Curves for a typical 12 kV, 630 A, 16 kA vacuum interrupter

Nr the number of closing-opening operations allowed for the circuit breaker

Ia the current at the time of tripping of the circuit breaker

Calculation of Directional Coef

The directional coefficient is calculated according to the formula:



Directional Coef

B

A

I

I

f

r

=

= −

log

log

.2 2609


Ir Rated operating current = 630 A

If Rated fault current = 16 kA

A Op number rated = 30000

B Op number fault = 20

Calculation for estimating the remaining life

Figure 306 shows that there are 30,000 possible operations at the rated operatingcurrent of 630 A and 20 operations at the rated fault current 16 kA. Therefore, ifthe tripping current is 10 kA, one operation at 10 kA is equivalent to30,000/60=500 operations at the rated current. It is also assumed that prior to thistripping, the remaining life of the circuit breaker is 15,000 operations. Therefore,after one operation of 10 kA, the remaining life of the circuit breaker is15,000-500=14,500 at the rated operating current.

Spring-charged indicationFor normal operation of the circuit breaker, the circuit breaker spring should becharged within a specified time. Therefore, detecting long spring-charging timeindicates that it is time for the circuit breaker maintenance. The last value of thespring-charging time can be used as a service value.

Gas pressure supervisionThe gas pressure supervision monitors the gas pressure inside the arc chamber.When the pressure becomes too low compared to the required value, the circuitbreaker operations are locked. A binary input is available based on the pressurelevels in the function, and alarms are generated based on these inputs.

7.1.6 SignalsTable 477: SSCBR Input signals




BLOCK BOOLEAN 0=False Block input status

POSOPEN BOOLEAN 0=False Signal for open position of apparatus from I/O

POSCLOSE BOOLEAN 0=False Signal for closeposition of apparatus from I/O




Name Type Default DescriptionPRES_ALM_IN BOOLEAN 0=False Binary pressure alarm input

PRES_LO_IN BOOLEAN 0=False Binary pressure input for lockout indication

SPR_CHR_ST BOOLEAN 0=False CB spring charging started input

SPR_CHR BOOLEAN 0=False CB spring charged input

RST_IPOW BOOLEAN 0=False Reset accumulation energy

RST_CB_WEAR BOOLEAN 0=False Reset input for CB remaining life and operationcounter

RST_TRV_T BOOLEAN 0=False Reset input for CB closing and opening travel times

RST_SPR_T BOOLEAN 0=False Reset input for the charging time of the CB spring

Table 478: SSCBR Output signals

Name Type DescriptionTRV_T_OP_ALM BOOLEAN CB open travel time exceeded set value

TRV_T_CL_ALM BOOLEAN CB close travel time exceeded set value

SPR_CHR_ALM BOOLEAN Spring charging time has crossed the set value

OPR_ALM BOOLEAN Number of CB operations exceeds alarm limit

OPR_LO BOOLEAN Number of CB operations exceeds lockout limit

IPOW_ALM BOOLEAN Accumulated currents power (Iyt),exceeded alarmlimit

IPOW_LO BOOLEAN Accumulated currents power (Iyt),exceededlockout limit

CB_LIFE_ALM BOOLEAN Remaining life of CB exceeded alarm limit

MON_ALM BOOLEAN CB 'not operated for long time' alarm

PRES_ALM BOOLEAN Pressure below alarm level

PRES_LO BOOLEAN Pressure below lockout level

OPENPOS BOOLEAN CB is in open position

INVALIDPOS BOOLEAN CB is in invalid position (not positively open orclosed)

CLOSEPOS BOOLEAN CB is in closed position

7.1.7 SettingsTable 479: SSCBR Non group settings



Acc stop current 5.00...500.00 A 0.01 10.00 RMS current setting below which engyacm stops

Open alarm time 0...200 ms 1 40 Alarm level setting for open travel time inms

Close alarm time 0...200 ms 1 40 Alarm level Setting for close travel timein ms




Parameter Values (Range) Unit Step Default DescriptionOpening time Cor 0...100 ms 1 10 Correction factor for open travel time in ms

Closing time Cor 0...100 ms 1 10 Correction factor for CB close travel timein ms

Spring charge time 0...60000 ms 10 1000 Setting of alarm for spring charging timeof CB in ms

Counter initial Val 0...9999 1 0 The operation numbers counterinitialization value

Alarm Op number 0...9999 1 200 Alarm limit for number of operations

Lockout Op number 0...9999 1 300 Lock out limit for number of operations

Current exponent 0.00...2.00 0.01 2.00 Current exponent setting for energycalculation

Difference Cor time -10...10 ms 1 5 Corr. factor for time dif in aux. and maincontacts open time

Alm Acc currents Pwr 0.00...20000.00 0.01 2500.00 Setting of alarm level for accumulatedcurrents power

LO Acc currents Pwr 0.00...20000.00 0.01 2500.00 Lockout limit setting for accumulatedcurrents power

Ini Acc currents Pwr 0.00...20000.00 0.01 0.00 Initial value for accumulation energy (Iyt)

Directional Coef -3.00...-0.50 0.01 -1.50 Directional coefficient for CB lifecalculation

Initial CB Rmn life 0...9999 1 5000 Initial value for the CB remaining life

Rated Op current 100.00...5000.00 A 0.01 1000.00 Rated operating current of the breaker

Rated fault current 500.00...75000.00 A 0.01 5000.00 Rated fault current of the breaker

Op number rated 1...99999 1 10000 Number of operations possible at ratedcurrent

Op number fault 1...10000 1 1000 Number of operations possible at ratedfault current

Life alarm level 0...99999 1 500 Alarm level for CB remaining life

Pressure alarm time 0...60000 ms 1 10 Time delay for gas pressure alarm in ms

Pres lockout time 0...60000 ms 10 10 Time delay for gas pressure lockout in ms

Inactive Alm days 0...9999 1 2000 Alarm limit value of the inactive dayscounter

Ini inactive days 0...9999 1 0 Initial value of the inactive days counter

Inactive Alm hours 0...23 h 1 0 Alarm time of the inactive days counterin hours



7.1.8 Monitored dataTable 480: SSCBR Monitored data

Name Type Values (Range) Unit DescriptionT_TRV_OP FLOAT32 0...60000 ms Travel time of the CB

during opening operation

T_TRV_CL FLOAT32 0...60000 ms Travel time of the CBduring closing operation

T_SPR_CHR FLOAT32 0.00...99.99 s The charging time of theCB spring

NO_OPR INT32 0...99999 Number of CB operationcycle

INA_DAYS INT32 0...9999 The number of days CBhas been inactive

CB_LIFE_A INT32 -9999...9999 CB Remaining life phaseA

CB_LIFE_B INT32 -9999...9999 CB Remaining life phaseB

CB_LIFE_C INT32 -9999...9999 CB Remaining life phaseC

IPOW_A FLOAT32 0.000...30000.000

Accumulated currentspower (Iyt), phase A

IPOW_B FLOAT32 0.000...30000.000

Accumulated currentspower (Iyt), phase B

IPOW_C FLOAT32 0.000...30000.000

Accumulated currentspower (Iyt), phase C

SSCBR Enum 1=on2=blocked3=test4=test/blocked5=off

Status

7.1.9 Technical dataTable 481: SSCBR Technical data

Characteristic ValueCurrent measuring accuracy ±1.5% or ±0.002 x In

(at currents in the range of 0.1…10 x In)±5.0%(at currents in the range of 10…40 x In)


Travelling time measurement +10 ms / -0 ms



7.1.10 Technical revision historyTable 482: SSCBR Technical revision history

Technical revision ChangeB Added the possibility to reset spring charge time

and breaker travel times

C Removed the DIFTRVTOPALM andDIFTRVTCLALM outputs and the correspondingOpen Dif alarm time and Close Dif alarm timesetting parameters

D The Operation cycle setting parameter renamedto Initial CB Rmn life. The IPOW_A (_B, _C)range changed.



Section 8 Measurement functions

8.1 Basic measurements

8.1.1 FunctionsThe three-phase current measurement function CMMXU is used for monitoringand metering the phase currents of the power system.

The three-phase voltage measurement function VMMXU is used for monitoringand metering the phase-to-phase voltages of the power system. The phase-to-earthvoltages are also available in VMMXU.

The residual current measurement function RESCMMXU is used for monitoringand metering the residual current of the power system.

The residual voltage measurement function RESVMMXU is used for monitoringand metering the residual voltage of the power system.

The sequence current measurement CSMSQI is used for monitoring and meteringthe phase sequence currents.

The sequence voltage measurement VSMSQI is used for monitoring and meteringthe phase sequence voltages.

The frequency measurement FMMXU is used for monitoring and metering thepower system frequency.

The three-phase power and energy measurement PEMMXU is used for monitoringand metering active power (P), reactive power (Q), apparent power (S) and powerfactor (PF) and for calculating the accumulated energy separately as forwardactive, reversed active, forward reactive and reversed reactive. PEMMXUcalculates these quantities using the fundamental frequency phasors, that is, theDFT values of the measured phase current and phase voltage signals.

The information of the measured quantity is available for the operator both locallyin LHMI and remotely to a network control center with communication.

If the measured data is within parentheses, there are some problemsto express the data.

1MRS756887 G Section 8Measurement functions


8.1.2 Measurement functionalityThe functions can be enabled or disabled with the Operation setting. Thecorresponding parameter values are "On" and "Off".

Some of the measurement functions operate on two alternative measurementmodes: "DFT" and "RMS". The measurement mode is selected with the XMeasurement mode setting. Depending on the measuring function if themeasurement mode cannot be selected, the measuring mode is "DFT".

Demand value calculationThe demand values are calculated separately for each measurement function andper phase when applicable. The available measurement modes are "Linear" and"Logarithmic". The "Logarithmic" measurement mode is only effective for phasecurrent and residual current demand value calculations. The demand valuecalculation mode is selected with the setting parameter Configuration/Measurements/A demand Av mode. The time interval for all demand valuecalculations is selected with the setting parameter Configuration/Measurements/Demand interval.

If the Demand interval setting is set to "15 minutes", for example, the demandvalues are updated every quarter of an hour. The demand time interval issynchronized to the real-time clock of the IED. When the demand time interval orcalculation mode is changed, it initializes the demand value calculation. For thevery first demand value calculation interval, the values are stated as invalid untilthe first refresh is available.

The "Linear" calculation mode uses the periodic sliding average calculation of themeasured signal over the demand time interval. A new demand value is obtainedonce in a minute, indicating the analog signal demand over the demand timeinterval proceeding the update time. The actual rolling demand values are stored inthe memory until the value is updated at the end of the next time interval.

The "Logarithmic" calculation mode uses the periodic calculation using a log10function over the demand time interval to replicate thermal demand ammeters. Thelogarithmic demand calculates a snapshot of the analog signal every 1/15 x demandtime interval.

Each measurement function has its own recorded data values. In IED, these arefound in Monitoring/Recorded data/Measurements. In the technical manualthese are listed in the monitored data section of each measurement function. Thesevalues are periodically updated with the maximum and minimum demand values.The time stamps are provided for both values.

Value reportingThe measurement functions are capable of reporting new values for networkcontrol center (SCADA system) based on the following functions:

Section 8 1MRS756887 GMeasurement functions


• Zero-point clamping• Deadband supervision• Limit value supervision

In the three-phase voltage measurement function VMMXU thesupervision functions are based on the phase-to-phase voltages.However, the phase-to-earth voltage values are also reported withthe phase-to-phase voltages.

Zero-point clampingA measured value under the zero-point clamping limit is forced to zero. Thisallows the noise in the input signal to be ignored. The active clamping functionforces both the actual measurement value and the angle value of the measuredsignal to zero. In the three-phase or sequence measuring functions, each phase orsequence component has a separate zero-point clamping function. The zero-valuedetection operates so that once the measured value exceeds or falls below the valueof the zero-clamping limit, new values are reported.

Table 483: Zero-point clamping limits

Function Zero-clamping limitThree-phase current measurement (CMMXU) 1% of nominal (In)

Three-phase voltage measurement (VMMXU) 1% of nominal (Un)

Residual current measurement (RESCMMXU) 1% of nominal (In)

Residual voltage measurement (RESVMMXU) 1% of nominal (Un)

Phase sequence current measurement (CSMSQI) 1% of the nominal (In)

Phase sequence voltage measurement(VSMSQI)

1% of the nominal (Un)

Three-phase power and energy measurement(PEMMXU)

1.5% of the nominal (Sn)

When the frequency measurement function FMMXU is unable tomeasure the network frequency in the undervoltage situation, themeasured values are set to the nominal and also the qualityinformation of the data set accordingly. The undervoltage limit isfixed to 10 percent of the nominal for the frequency measurement.

Limit value supervisionThe limit value supervision function indicates whether the measured value ofX_INST exceeds or falls below the set limits. The measured value has thecorresponding range information X_RANGE and has a value in the range of 0 to 4:



• 0: "normal"• 1: "high"• 2: "low"• 3: "high-high"• 4: "low-low"

The range information changes and the new values are reported.

GUID-AAAA7367-377C-4743-A2D0-8DD4941C585D V1 EN

Figure 307: Presentation of operating limits

The range information can also be decoded into boolean output signals on some ofthe measuring functions and the number of phases required to exceed or undershootthe limit before activating the outputs and can be set with the Num of phases settingin the three-phase measurement functions CMMXU and VMMXU. The limitsupervision boolean alarm and warning outputs can be blocked.

Table 484: Settings for limit value supervision

Function Settings for limit value supervisionThree-phase current measurement(CMMXU)

High limit A high limit

Low limit A low limit

High-high limit A high high limit

Low-low limit A low low limit

Three-phase voltage measurement(VMMXU)

High limit V high limit

Low limit V low limit

High-high limit V high high limit

Low-low limit V low low limit




Function Settings for limit value supervisionResidual current measurement(RESCMMXU)

High limit A high limit res

Low limit -

High-high limit A Hi high limit res

Low-low limit -

Frequency measurement (FMMXU) High limit F high limit

Low limit F low limit

High-high limit F high high limit

Low-low limit F low low limit

Residual voltage measurement(RESVMMXU)

High limit V high limit res

Low limit -

High-high limit V Hi high limit res

Low-low limit -

Phase sequence current measurement(CSMSQI)

High limit Ps Seq A high limit, Ng SeqA high limit, Zro A high limit

Low limit Ps Seq A low limit, Ng SeqA low limit, Zro A low limit

High-high limit Ps Seq A Hi high Lim, NgSeq A Hi high Lim, Zro A Hihigh Lim

Low-low limit Ps Seq A low low Lim, NgSeq A low low Lim, Zro Alow low Lim

Phase sequence voltage measurement(VSMSQI)

High limit Ps Seq V high limit, Ng SeqV high limit, Zro V high limit

Low limit Ps Seq V low limit, Ng SeqV low limit, Zro V low limit

High-high limit Ps Seq V Hi high Lim, NgSeq V Hi high Lim, Zro V Hihigh Lim

Low-low limit Ps Seq V low low Lim, NgSeq V low low Lim,

Three-phase power and energymeasurement (PEMMXU)

High limit -

Low limit -

High-high limit -

Low-low limit -

Deadband supervisionThe deadband supervision function reports the measured value according tointegrated changes over a time period.



GUID-63CA9A0F-24D8-4BA8-A667-88632DF53284 V1 EN

Figure 308: Integral deadband supervision

The deadband value used in the integral calculation is configured with the Xdeadband setting. The value represents the percentage of the difference betweenthe maximum and minimum limit in the units of 0.001 percent x seconds.

The reporting delay of the integral algorithms in seconds is calculated with theformula:

t sdeadband

Y( )

(max min) /

%=

− ×

×

1000

100∆

GUID-5381484E-E205-4548-A846-D3519578384B V1 EN (Equation 70)

Example for CMMXU:

A deadband = 2500 (2.5% of the total measuring range of 40)

I_INST_A = I_DB_A = 0.30

If I_INST_A changes to 0.40, the reporting delay is:

t s s( )( ) /

. . %=

− ×

− ×=

40 0 2500 1000

0 40 0 30 10010

GUID-D1C387B1-4F2E-4A28-AFEA-431687DDF9FE V1 EN

Table 485: Parameters for deadband calculation

Function Settings Maximum/minimum (=range)Three-phase currentmeasurement (CMMXU)

A deadband 40 / 0 (=40xIn)

Three-phase voltagemeasurement (VMMXU)

V Deadband 4 / 0 (=4xUn)

Residual current measurement(RESCMMXU)

A deadband res 40 / 0 (=40xIn)

Residual voltage measurement(RESVMMXU)

V deadband res 4 / 0 (=4xUn)




Function Settings Maximum/minimum (=range)Frequency measurement(FMMXU)

F deadband 75 / 35 (=40Hz)

Phase sequence currentmeasurement (CSMSQI)

Ps Seq A deadband, Ng Seq Adeadband, Zro A deadband

40 / 0 (=40xIn)

Phase sequence voltagemeasurement (VSMSQI)

Ps Seq V deadband, Ng Seq Vdeadband, Zro V deadband

4/0 (=4xUn)

Three-phase power and energymeasurement (PEMMXU)

-

In the three-phase power and energy measurement functionPEMMXU, the deadband supervision is done separately forapparent power S, with the preset value of fixed 10 percent of theSn, and the power factor PF, with the preset values fixed at 0.10. .All the power measurement-related values P, Q, S and PF arereported simultaneously when either one of the S or PF valuesexceeds the preset limit.

Power and energy calculationThe three-phase power is calculated from the phase-to-earth voltages and phase-to-earth currents. The power measurement function is capable of calculating acomplex power based on the fundamental frequency component phasors (DFT).

S = ⋅ + ⋅ + ⋅(U I U I U IA A B B C C* * *

)

GUID-8BF2FBFE-B33B-4B49-86AA-C1B326BBBAC1 V1 EN (Equation 71)

Once the complex apparent power is calculated, P, Q, S and PF are calculated withthe equations:

P S= Re( )

GUID-92B45FA5-0B6B-47DC-9ADB-69E7EB30D53A V3 EN (Equation 72)

Q S= Im( )

GUID-CA5C1D5D-3AD9-468C-86A1-835525F8BE27 V2 EN (Equation 73)

S S P Q= = +2 2

GUID-B3999831-E376-4DAF-BF36-BA6F761230A9 V2 EN (Equation 74)

CosP

Sϕ =

GUID-D729F661-94F9-48B1-8FA0-06E84A6F014C V2 EN (Equation 75)

Depending on the unit multiplier selected with Power unit Mult, the calculatedpower values are presented in units of kVA/kW/kVAr or in units of MVA/MW/MVAr.



GUID-9947B4F2-CD26-4F85-BF57-EAF1593AAE1B V1 EN

Figure 309: Complex power and power quadrants

Table 486: Power quadrants

Quadrant Current P Q PF PowerQ1 Lagging + + 0…+1.00 +ind

Q2 Lagging - + 0…-1.00 -cap

Q3 Leading - - 0…-1.00 -ind

Q4 Leading + - 0…+1.00 +cap

The active power P direction can be selected between forward and reverse withActive power Dir and correspondingly the reactive power Q direction can beselected with Reactive power Dir. This affects also the accumulated energy directions.

The accumulated energy is calculated separately as forward active(EA_FWD_ACM), reverse active (EA_RV_ACM), forward reactive (ER_FWD_ACM)and reverse reactive (ER_RV_ACM). Depending on the value of the unit multiplierselected with Energy unit Mult, the calculated power values are presented in unitsof kWh/kVArh or in units of MWh/MVArh.

When the energy counter reaches its defined maximum value, the counter value isreset and restarted from zero. Changing the value of the Energy unit Mult settingresets the accumulated energy values to the initial values, that is, EA_FWD_ACM toForward Wh Initial, EA_RV_ACM to Reverse Wh Initial, ER_FWD_ACM toForward WArh Initial and ER_RV_ACM to Reverse WArh Initial. It is also possibleto reset the accumulated energy to initial values through a parameter or with theRSTACM input.



Sequence componentsThe phase-sequence components are calculated using the phase currents and phasevoltages. More information on calculating the phase-sequence components can befound in Calculated measurements in this manual.

8.1.3 Measurement function applicationsThe measurement functions are used for power system measurement, supervisionand reporting to LHMI, a monitoring tool within PCM600, or to the station level,for example, with IEC 61850. The possibility to continuously monitor themeasured values of active power, reactive power, currents, voltages, power factorsand so on, is vital for efficient production, transmission, and distribution ofelectrical energy. It provides a fast and easy overview of the present status of thepower system to the system operator. Additionally, it can be used during testingand commissioning of protection and control IEDs to verify the proper operationand connection of instrument transformers, that is, the current transformers (CTs)and voltage transformers (VTs). The proper operation of the IED analogmeasurement chain can be verified during normal service by a periodic comparisonof the measured value from the IED to other independent meters.

When the zero signal is measured, the noise in the input signal can still producesmall measurement values. The zero point clamping function can be used to ignorethe noise in the input signal and, hence, prevent the noise to be shown in the userdisplay. The zero clamping is done for the measured analog signals and angle values.

The demand values are used to neglect sudden changes in the measured analogsignals when monitoring long time values for the input signal. The demand valuesare linear average values of the measured signal over a settable demand interval.The demand values are calculated for the measured analog three-phase currentsignals.

The limit supervision indicates, if the measured signal exceeds or goes below theset limits. Depending on the measured signal type, up to two high limits and up totwo low limits can be set for the limit supervision.

The deadband supervision reports a new measurement value if the input signal hasgone out of the deadband state. The deadband supervision can be used in valuereporting between the measurement point and operation control. When thedeadband supervision is properly configured, it helps in keeping thecommunication load in minimum and yet measurement values are reportedfrequently enough.

8.1.4 Three-phase current measurement CMMXU





Three-phase current measurement CMMXU 3I 3I




A070777 V2 EN


8.1.4.3 Signals

Table 487: CMMXU Input signals





Table 488: CMMXU Output signals

Name Type DescriptionHIGH_ALARM BOOLEAN High alarm

HIGH_WARN BOOLEAN High warning

LOW_WARN BOOLEAN Low warning

LOW_ALARM BOOLEAN Low alarm

8.1.4.4 Settings

Table 489: CMMXU Non group settings



Measurement mode 1=RMS2=DFT


Num of phases 1=1 out of 32=2 out of 33=3 out of 3

1=1 out of 3 Number of phases required by limitsupervision

A high high limit 0.00...40.00 xIn 1.40 High alarm current limit

A high limit 0.00...40.00 xIn 1.20 High warning current limit

A low limit 0.00...40.00 xIn 0.00 Low warning current limit

A low low limit 0.00...40.00 xIn 0.00 Low alarm current limit

A deadband 100...100000 2500 Deadband configuration value forintegral calculation. (percentage ofdifference between min and max as0,001 % s)




Table 490: CMMXU Monitored data

Name Type Values (Range) Unit DescriptionIL1-A FLOAT32 0.00...40.00 xIn Measured current

amplitude phase A

IL2-A FLOAT32 0.00...40.00 xIn Measured currentamplitude phase B

IL3-A FLOAT32 0.00...40.00 xIn Measured currentamplitude phase C

Max demand IL1 FLOAT32 0.00...40.00 xIn Maximum demand forPhase A

Max demand IL2 FLOAT32 0.00...40.00 xIn Maximum demand forPhase B

Max demand IL3 FLOAT32 0.00...40.00 xIn Maximum demand forPhase C

Min demand IL1 FLOAT32 0.00...40.00 xIn Minimum demand forPhase A

Min demand IL2 FLOAT32 0.00...40.00 xIn Minimum demand forPhase B

Min demand IL3 FLOAT32 0.00...40.00 xIn Minimum demand forPhase C

Time max demandIL1

Timestamp Time of maximumdemand phase A

Time max demandIL2

Timestamp Time of maximumdemand phase B

Time max demandIL3

Timestamp Time of maximumdemand phase C

Time min demandIL1

Timestamp Time of minimumdemand phase A

Time min demandIL2

Timestamp Time of minimumdemand phase B

Time min demandIL3

Timestamp Time of minimumdemand phase C


Table 491: CMMXU Technical data


measured: fn ±2 Hz

±0.5% or ±0.002 x In(at currents in the range of 0.01...4.00 x In)

Suppression of harmonics DFT: -50 dB at f = n x fn, where n = 2, 3, 4, 5,…RMS: No suppression




Table 492: CMMXU Technical revision history

Technical revision ChangeB Menu changes

8.1.5 Three-phase voltage measurement VMMXU





Three-phase voltage measurement VMMXU 3U 3U


GUID-5B741292-7FA6-4DEA-8D16-B530FD16A0FE V1 EN


8.1.5.3 Signals

Table 493: VMMXU Input signals


voltage AB




Table 494: VMMXU Output signals



LOW_WARN BOOLEAN Low warning

LOW_ALARM BOOLEAN Low alarm



8.1.5.4 Settings

Table 495: VMMXU Non group settings





Num of phases 1=1 out of 32=2 out of 33=3 out of 3

1=1 out of 3 Number of phases required by limitsupervision

V high high limit 0.00...4.00 xUn 1.40 High alarm voltage limit

V high limit 0.00...4.00 xUn 1.20 High warning voltage limit

V low limit 0.00...4.00 xUn 0.00 Low warning voltage limit

V low low limit 0.00...4.00 xUn 0.00 Low alarm voltage limit

V deadband 100...100000 10000 Deadband configuration value forintegral calculation. (percentage ofdifference between min and max as0,001 % s)


Table 496: VMMXU Monitored data

Name Type Values (Range) Unit DescriptionU12-kV FLOAT32 0.00...4.00 xUn Measured phase to

phase voltage amplitudephase AB

U23-kV FLOAT32 0.00...4.00 xUn Measured phase tophase voltage amplitudephase BC

U31-kV FLOAT32 0.00...4.00 xUn Measured phase tophase voltage amplitudephase CA


Table 497: VMMXU Technical data


measured: fn ±2 HzAt voltages in range 0.01…1.15 x Un

±0.5% or ±0.002 x Un




8.1.6 Residual current measurement RESCMMXU





Residual current measurement RESCMMXU Io Io


A070778 V2 EN


8.1.6.3 Signals

Table 498: RESCMMXU Input signals



Table 499: RESCMMXU Output signals



8.1.6.4 Settings

Table 500: RESCMMXU Non group settings





A Hi high limit res 0.00...40.00 xIn 0.20 High alarm current limit

A high limit res 0.00...40.00 xIn 0.05 High warning current limit

A deadband res 100...100000 2500 Deadband configuration value forintegral calculation. (percentage ofdifference between min and max as0,001 % s)




Table 501: RESCMMXU Monitored data

Name Type Values (Range) Unit DescriptionIo-A FLOAT32 0.00...40.00 xIn Measured residual

current

Max demand Io FLOAT32 0.00...40.00 xIn Maximum demand forresidual current

Min demand Io FLOAT32 0.00...40.00 xIn Minimum demand forresidual current

Time max demand Io Timestamp Time of maximumdemand residual current

Time min demand Io Timestamp Time of minimumdemand residual current


Table 502: RESCMMXU Technical data


±0.5% or ±0.002 x In(at currents in the range of 0.01...4.00 x In)



Table 503: RESCMMXU Technical revision history


8.1.7 Residual voltage measurement RESVMMXU





Residual voltage measurement RESVMMXU Uo U0




A070779 V2 EN


8.1.7.3 Signals

Table 504: RESVMMXU Input signals

Name Type Default DescriptionUo SIGNAL 0 Residual voltage


Table 505: RESVMMXU Output signals



8.1.7.4 Settings

Table 506: RESVMMXU Non group settings





V Hi high limit res 0.00...4.00 xUn 0.20 High alarm voltage limit

V high limit res 0.00...4.00 xUn 0.05 High warning voltage limit

V deadband res 100...100000 10000 Deadband configuration value forintegral calculation. (percentage ofdifference between min and max as0,001 % s)


Table 507: RESVMMXU Monitored data

Name Type Values (Range) Unit DescriptionUo-kV FLOAT32 0.00...4.00 xUn Measured residual

voltage




Table 508: RESVMMXU Technical data


measured: f/fn = ±2 Hz

±0.5% or ±0.002 x Un



Table 509: RESVMMXU Technical revision history


8.1.8 Frequency measurement FMMXU





Frequency measurement FMMXU1 F F


GUID-5CCF8F8C-E1F4-421B-8BE9-C0620F7446A7 V1 EN


8.1.8.3 Signals

Table 510: FMMXU Input signals

Name Type Default DescriptionF SIGNAL — Measured system frequency



8.1.8.4 Settings

Table 511: FMMXU Non group settings



F high high limit 35.00...75.00 Hz 60.00 High alarm frequency limit

F high limit 35.00...75.00 Hz 55.00 High warning frequency limit

F low limit 35.00...75.00 Hz 45.00 Low warning frequency limit

F low low limit 35.00...75.00 Hz 40.00 Low alarm frequency limit

F deadband 100...100000 1000 Deadband configuration value forintegral calculation (percentage ofdifference between min and max as0,001 % s)


Table 512: FMMXU Monitored data

Name Type Values (Range) Unit Descriptionf-Hz FLOAT32 35.00...75.00 Hz Measured frequency


Table 513: FMMXU Technical data

Characteristic ValueOperation accuracy ±10 mHz

(in measurement range 35 - 75 Hz)

8.1.9 Sequence current measurement CSMSQI





Sequence current measurement CSMSQI I1, I2, I0 I1, I2, I0


A070784 V2 EN




8.1.9.3 Signals

Table 514: CSMSQI Input signals

Name Type Default DescriptionI0 SIGNAL 0 Zero sequence current

I1 SIGNAL 0 Positive sequence current


8.1.9.4 Settings

Table 515: CSMSQI Non group settings



Ps Seq A Hi high Lim 0.00...40.00 xIn 1.40 High alarm current limit for positivesequence current

Ps Seq A high limit 0.00...40.00 xIn 1.20 High warning current limit for positivesequence current

Ps Seq A low limit 0.00...40.00 xIn 0.00 Low warning current limit for positivesequence current

Ps Seq A low low Lim 0.00...40.00 xIn 0.00 Low alarm current limit for positivesequence current

Ps Seq A deadband 100...100000 2500 Deadband configuration value forpositive sequence current for integralcalculation. (percentage of differencebetween min and max as 0,001 % s)

Ng Seq A Hi high Lim 0.00...40.00 xIn 0.20 High alarm current limit for negativesequence current

Ng Seq A High limit 0.00...40.00 xIn 0.05 High warning current limit for negativesequence current

Ng Seq A low limit 0.00...40.00 xIn 0.00 Low warning current limit for negativesequence current

Ng Seq A low low Lim 0.00...40.00 xIn 0.00 Low alarm current limit for negativesequence current

Ng Seq A deadband 100...100000 2500 Deadband configuration value fornegative sequence current for integralcalculation. (percentage of differencebetween min and max as 0,001 % s)

Zro A Hi high Lim 0.00...40.00 xIn 0.20 High alarm current limit for zerosequence current

Zro A High limit 0.00...40.00 xIn 0.05 High warning current limit for zerosequence current




Parameter Values (Range) Unit Step Default DescriptionZro A low limit 0.00...40.00 xIn 0.00 Low warning current limit for zero

sequence current

Zro A low low Lim 0.00...40.00 xIn 0.00 Low alarm current limit for zerosequence current

Zro A deadband 100...100000 2500 Deadband configuration value for zerosequence current for integral calculation.(percentage of difference between minand max as 0,001 % s)


Table 516: CSMSQI Monitored data

Name Type Values (Range) Unit DescriptionNgSeq-A FLOAT32 0.00...40.00 xIn Measured negative

sequence current

PsSeq-A FLOAT32 0.00...40.00 xIn Measured positivesequence current

ZroSeq-A FLOAT32 0.00...40.00 xIn Measured zerosequence current


Table 517: CSMSQI Technical data


measured: f/fn = ±2 Hz

±1.0% or ±0.002 x Inat currents in the range of 0.01...4.00 x In


8.1.10 Sequence voltage measurement VSMSQI





Sequence voltage measurement VSMSQI U1, U2, U0 U1, U2, U0




GUID-63393283-E2C1-406A-9E70-847662D83CFC V2 EN


8.1.10.3 Signals

Table 518: VSMSQI Input signals

Name Type Default DescriptionU0 SIGNAL 0 Zero sequence voltage



8.1.10.4 Settings

Table 519: VSMSQI Non group settings



Ps Seq V Hi high Lim 0.00...4.00 xUn 1.40 High alarm voltage limit for positivesequence voltage

Ps Seq V high limit 0.00...4.00 xUn 1.20 High warning voltage limit for positivesequence voltage

Ps Seq V low limit 0.00...4.00 xUn 0.00 Low warning voltage limit for positivesequence voltage

Ps Seq V low low Lim 0.00...4.00 xUn 0.00 Low alarm voltage limit for positivesequence voltage

Ps Seq V deadband 100...100000 10000 Deadband configuration value forpositive sequence voltage for integralcalculation. (percentage of differencebetween min and max as 0,001 % s)

Ng Seq V Hi high Lim 0.00...4.00 xUn 0.20 High alarm voltage limit for negativesequence voltage

Ng Seq V High limit 0.00...4.00 xUn 0.05 High warning voltage limit for negativesequence voltage

Ng Seq V low limit 0.00...4.00 xUn 0.00 Low warning voltage limit for negativesequence voltage

Ng Seq V low low Lim 0.00...4.00 xUn 0.00 Low alarm voltage limit for negativesequence voltage




Parameter Values (Range) Unit Step Default DescriptionNg Seq V deadband 100...100000 10000 Deadband configuration value for

negative sequence voltage for integralcalculation. (percentage of differencebetween min and max as 0,001 % s)

Zro V Hi high Lim 0.00...4.00 xUn 0.20 High alarm voltage limit for zerosequence voltage

Zro V High limit 0.00...4.00 xUn 0.05 High warning voltage limit for zerosequence voltage

Zro V low limit 0.00...4.00 xUn 0.00 Low warning voltage limit for zerosequence voltage

Zro V low low Lim 0.00...4.00 xUn 0.00 Low alarm voltage limit for zerosequence voltage

Zro V deadband 100...100000 10000 Deadband configuration value for zerosequence voltage for integral calculation.(percentage of difference between minand max as 0,001 % s)


Table 520: VSMSQI Monitored data

Name Type Values (Range) Unit DescriptionNgSeq-kV FLOAT32 0.00...4.00 xUn Measured negative

sequence voltage

PsSeq-kV FLOAT32 0.00...4.00 xUn Measured positivesequence voltage

ZroSeq-kV FLOAT32 0.00...4.00 xUn Measured zerosequence voltage


Table 521: VSMSQI Technical data


measured: fn ±2 HzAt voltages in range 0.01…1.15 x Un

±1.0% or ±0.002 x Un


8.1.11 Three-phase power and energy measurement PEMMXU





Three-phase power and energymeasurement

PEMMXU P, E P, E




GUID-E38A24DA-85CE-4246-9C3F-DFC6FDAEA302 V1 EN


8.1.11.3 Signals

Table 522: PEMMXU Input signals




U_A SIGNAL 0 Phase A voltage

U_B SIGNAL 0 Phase B voltage

U_C SIGNAL 0 Phase C voltage

RSTACM BOOLEAN 0=False Reset of accumulated energy reading

8.1.11.4 Settings

Table 523: PEMMXU Non group settings



Power unit Mult 3=Kilo6=Mega

3=Kilo Unit multiplier for presentation of thepower related values

Energy unit Mult 3=Kilo6=Mega

3=Kilo Unit multiplier for presentation of theenergy related values

Active power Dir 1=Forward2=Reverse

1=Forward Direction of active power flow: Forward,Reverse

Reactive power Dir 1=Forward2=Reverse

1=Forward Direction of reactive power flow:Forward, Reverse

Forward Wh Initial 0...999999999 1 0 Preset Initial value for forward activeenergy

Reverse Wh Initial 0...999999999 1 0 Preset Initial value for reverse activeenergy

Forward VArh Initial 0...999999999 1 0 Preset Initial value for forward reactiveenergy

Reverse VArh Initial 0...999999999 1 0 Preset Initial value for reverse reactiveenergy




Table 524: PEMMXU Monitored data

Name Type Values (Range) Unit DescriptionS-kVA FLOAT32 -999999.9...9999

99.9kVA Total Apparent Power

P-kW FLOAT32 -999999.9...999999.9

kW Total Active Power

Q-kVAr FLOAT32 -999999.9...999999.9

kVAr Total Reactive Power

PF FLOAT32 -1.00...1.00 Average Power factor

Max demand S FLOAT32 -999999.9...999999.9

kVA Maximum demand valueof apparent power

Min demand S FLOAT32 -999999.9...999999.9

kVA Minimum demand valueof apparent power

Max demand P FLOAT32 -999999.9...999999.9

kW Maximum demand valueof active power

Min demand P FLOAT32 -999999.9...999999.9

kW Minimum demand valueof active power

Max demand Q FLOAT32 -999999.9...999999.9

kVAr Maximum demand valueof reactive power

Min demand Q FLOAT32 -999999.9...999999.9

kVAr Minimum demand valueof reactive power

Time max dmd S Timestamp Time of maximumdemand

Time min dmd S Timestamp Time of minimumdemand

Time max dmd P Timestamp Time of maximumdemand

Time min dmd P Timestamp Time of minimumdemand

Time max dmd Q Timestamp Time of maximumdemand

Time min dmd Q Timestamp Time of minimumdemand


Table 525: PEMMXU Technical data

Characteristic ValueOperation accuracy At all three currents in range 0.10…1.20 x In

At all three voltages in range 0.50…1.15 x UnAt the frequency fn ±1 HzActive power and energy in range |PF| > 0.71Reactive power and energy in range |PF| < 0.71

±1.5% for power (S, P and Q)±0.015 for power factor±1.5% for energy




8.2 Disturbance recorder

8.2.1 FunctionalityThe IED is provided with a disturbance recorder featuring up to 12 analog and 64binary signal channels. The analog channels can be set to record either thewaveform or the trend of the currents and voltage measured.

The analog channels can be set to trigger the recording function when the measuredvalue falls below or exceeds the set values. The binary signal channels can be set tostart a recording on the rising or the falling edge of the binary signal or both.

By default, the binary channels are set to record external or internal IED signals,for example the start or trip signals of the IED stages, or external blocking orcontrol signals. Binary IED signals such as a protection start or trip signal, or anexternal IED control signal over a binary input can be set to trigger the recording.The recorded information is stored in a non-volatile memory and can be uploadedfor subsequent fault analysis.

8.2.1.1 Recorded analog inputs

The user can map any analog signal type of the IED to each analog channel of thedisturbance recorder by setting the Channel selection parameter of thecorresponding analog channel. In addition, the user can enable or disable eachanalog channel of the disturbance recorder by setting the Operation parameter ofthe corresponding analog channel to "on" or "off".

All analog channels of the disturbance recorder that are enabled and have a validsignal type mapped are included in the recording.

8.2.1.2 Triggering alternatives

The recording can be triggered by any or several of the following alternatives:

• Triggering according to the state change of any or several of the binarychannels of the disturbance recorder. The user can set the level sensitivity withthe Level trigger mode parameter of the corresponding binary channel.

• Triggering on limit violations of the analog channels of the disturbancerecorder (high and low limit)

• Manual triggering via the Trig recording parameter (LHMI or communication)• Periodic triggering.

Regardless of the triggering type, each recording generates events through statechanges of the Recording started, Recording made and Recording stored statusparameters. The Recording stored parameter indicates that the recording has beenstored to the non-volatile memory. In addition, every analog channel and binarychannel of the disturbance recorder has its own Channel triggered parameter.



Manual trigger has the Manual triggering parameter and periodic trigger has thePeriodic triggering parameter.

Triggering by binary channelsInput signals for the binary channels of the disturbance recorder can be formedfrom any of the digital signals that can be dynamically mapped. A change in thestatus of a monitored signal triggers the recorder according to the configuration andsettings. Triggering on the rising edge of a digital input signal means that therecording sequence starts when the input signal is activated. Correspondingly,triggering on the falling edge means that the recording sequence starts when theactive input signal resets. It is also possible to trigger from both edges. In addition,if preferred, the monitored signal can be non-triggering. The trigger setting can beset individually for each binary channel of the disturbance recorder with the Leveltrigger mode parameter of the corresponding binary channel.

Triggering by analog channelsThe trigger level can be set for triggering in a limit violation situation. The user canset the limit values with the High trigger level and Low trigger level parameters ofthe corresponding analog channel. Both high level and low level violationtriggering can be active simultaneously for the same analog channel. If the durationof the limit violation condition exceeds the filter time of approximately 50 ms, therecorder triggers. In case of a low level limit violation, if the measured value fallsbelow approximately 0.05 during the filter time, the situation is considered to be acircuit-breaker operation and therefore, the recorder does not trigger. This is usefulespecially in undervoltage situations. The filter time of approximately 50 ms iscommon to all the analog channel triggers of the disturbance recorder. The valueused for triggering is the calculated peak-to-peak value. Either high or low analogchannel trigger can be disabled by setting the corresponding trigger level parameterto zero.

Manual triggeringThe recorder can be triggered manually via the LHMI or via communication bysetting the Trig recording parameter to TRUE.

Periodic triggeringPeriodic triggering means that the recorder automatically makes a recording atcertain time intervals. The user can adjust the interval with the Periodic trig timeparameter. If the value of the parameter is changed, the new setting takes effectwhen the next periodic triggering occurs. Setting the parameter to zero disables thetriggering alternative and the setting becomes valid immediately. If a new non-zerosetting needs to be valid immediately, the user should first set the Periodic trigtime parameter to zero and then to the new value. The user can monitor the timeremaining to the next triggering with the Time to trigger monitored datawhich counts downwards.



8.2.1.3 Length of recordings

The user can define the length of a recording with the Record length parameter.The length is given as the number of fundamental cycles.

According to the memory available and the number of analog channels used, thedisturbance recorder automatically calculates the remaining amount of recordingsthat fit into the available recording memory. The user can see this information withthe Rem. amount of rec monitored data. The fixed memory size allocatedfor the recorder can fit in two recordings that are ten seconds long. The recordingscontain data from all analog and binary channels of the disturbance recorder, at thesample rate of 32 samples per fundamental cycle.

The user can view the number of recordings currently in memory with the Numberof recordings monitored data. The currently used memory space can beviewed with the Rec. memory used monitored data. It is shown as apercentage value.

The maximum number of recordings is 100.

8.2.1.4 Sampling frequencies

The sampling frequency of the disturbance recorder analog channels depends onthe set rated frequency. One fundamental cycle always contains the amount ofsamples set with the Storage rate parameter. Since the states of the binary channelsare sampled once per task execution of the disturbance recorder, the samplingfrequency of binary channels is 400 Hz at the rated frequency of 50 Hz and 480 Hzat the rated frequency of 60 Hz.

Table 526: Sampling frequencies of the disturbance recorder analog channels

Storage rate(samples perfundamentalcycle)

Recordinglength

Samplingfrequency ofanalogchannels, whenthe ratedfrequency is 50Hz

Samplingfrequency ofbinarychannels, whenthe ratedfrequency is 50Hz

Samplingfrequency ofanalogchannels, whenthe ratedfrequency is 60Hz

Samplingfrequency ofbinarychannels, whenthe ratedfrequency is 60Hz

32 1* Recordlength

1600 Hz 400 Hz 1920 Hz 480 Hz

16 2* Recordlength

800 Hz 400 Hz 960 Hz 480 Hz

8 4 * Recordlength

400 Hz 400 Hz 480 Hz 480 Hz



8.2.1.5 Uploading of recordings

The IED stores COMTRADE files to the C:\COMTRADE\ folder. The files can beuploaded with the PCM tool or any appropriate computer software that can accessthe C:\COMTRADE\ folder.

One complete disturbance recording consists of two COMTRADE file types: theconfiguration file and the data file. The file name is the same for both file types.The configuration file has .CFG and the data file .DAT as the file extension.

A070835 V1 EN

Figure 318: Disturbance recorder file naming

The naming convention of 8+3 characters is used in COMTRADE file naming. Thefile name is composed of the last two octets of the IED's IP number and a runningcounter, which has a range of 1...9999. A hexadecimal representation is used forthe IP number octets. The appropriate file extension is added to the end of the filename.

8.2.1.6 Deletion of recordings

There are several ways to delete disturbance recordings. The recordings can bedeleted individually or all at once.

Individual disturbance recordings can be deleted with the PCM tool or anyappropriate computer software, which can access the IED's C:\COMTRADE folder.The disturbance recording is not removed from the IED memory until both of thecorresponding COMTRADE files, .CFG and .DAT, are deleted. The user may haveto delete both of the files types separately, depending on the software used.



Deleting all disturbance recordings at once is done either with the PCM tool or anyappropriate computer software, or from the LHMI via the Clear/Disturbancerecords menu. Deleting all disturbance recordings at once also clears the pre-trigger recording in progress.

8.2.1.7 Storage mode

The disturbance recorder can capture data in two modes: waveform and trendmode. The user can set the storage mode individually for each trigger source withthe Storage mode parameter of the corresponding analog channel or binarychannel, the Stor. mode manual parameter for manual trigger and the Stor. modeperiodic parameter for periodic trigger.

In the waveform mode, the samples are captured according to the Storage rate andPre-trg length parameters.

In the trend mode, one value is recorded for each enabled analog channel, once perfundamental cycle. The recorded values are RMS values, which are scaled to peaklevel. The binary channels of the disturbance recorder are also recorded once perfundamental cycle in the trend mode.

Only post-trigger data is captured in trend mode.

The trend mode enables recording times of 32 * Record length.

8.2.1.8 Pre-trigger and post-trigger data

The waveforms of the disturbance recorder analog channels and the states of thedisturbance recorder binary channels are constantly recorded into the historymemory of the recorder. The user can adjust the percentage of the data durationpreceding the triggering, that is, the so-called pre-trigger time, with the Pre-trglength parameter. The duration of the data following the triggering, that is, the so-called post-trigger time, is the difference between the recording length and the pre-trigger time. Changing the pre-trigger time resets the history data and the currentrecording under collection.

8.2.1.9 Operation modes

Disturbance recorder has two operation modes: saturation and overwrite mode. Theuser can change the operation mode of the disturbance recorder with the Operationmode parameter.

Saturation modeIn saturation mode, the captured recordings cannot be overwritten with newrecordings. Capturing the data is stopped when the recording memory is full, thatis, when the maximum number of recordings is reached. In this case, the event is



sent via the state change (TRUE) of the Memory full parameter. When there ismemory available again, another event is generated via the state change (FALSE)of the Memory full parameter.

Overwrite modeWhen the operation mode is "Overwrite" and the recording memory is full, theoldest recording is overwritten with the pre-trigger data collected for the nextrecording. Each time a recording is overwritten, the event is generated via the statechange of the Overwrite of rec. parameter. The overwrite mode is recommended, ifit is more important to have the latest recordings in the memory. The saturationmode is preferred, when the oldest recordings are more important.

New triggerings are blocked in both the saturation and the overwrite mode until theprevious recording is completed. On the other hand, a new triggering can beaccepted before all pre-trigger samples are collected for the new recording. In sucha case, the recording is as much shorter as there were pre-trigger samples lacking.

8.2.1.10 Exclusion mode

Exclusion mode is on, when the value set with the Exclusion time parameter ishigher than zero. During the exclusion mode, new triggerings are ignored if thetriggering reason is the same as in the previous recording. The Exclusion timeparameter controls how long the exclusion of triggerings of same type is activeafter a triggering. The exclusion mode only applies to the analog and binarychannel triggerings, not to periodic and manual triggerings.

When the value set with the Exclusion time parameter is zero, the exclusion modeis disabled and there are no restrictions on the triggering types of the successiverecordings.

The exclusion time setting is global for all inputs, but there is an individual counterfor each analog and binary channel of the disturbance recorder, counting theremaining exclusion time. The user can monitor the remaining exclusion time withthe Exclusion time rem parameter of the corresponding analog or binary channel.The Exclusion time rem parameter counts downwards.

8.2.2 ConfigurationThe user can configure the disturbance recorder with the PCM600 tool or any toolsupporting the IEC 61850 standard.

The user can enable or disable the disturbance recorder with the Operationparameter under the Configuration/Disturbance recorder/General menu.

One analog signal type of the IED can be mapped to each of the analog channels ofthe disturbance recorder. The mapping is done with the Channel selectionparameter of the corresponding analog channel. The name of the analog channel isuser-configurable. The user can modify it by writing the new name to the Channelid text parameter of the corresponding analog channel.



Any external or internal digital signal of the IED which can be dynamicallymapped can be connected to the binary channels of the disturbance recorder. Thesesignals can be, for example, the start and trip signals from protection functionblocks or the external binary inputs of the IED. The connection is made withdynamic mapping to the binary channel of the disturbance recorder using, forexample, SMT of PCM600. It is also possible to connect several digital signals toone binary channel of the disturbance recorder. In that case, the signals can becombined with logical functions, for example AND and OR. The user canconfigure the name of the binary channel and modify it by writing the new name tothe Channel id text parameter of the corresponding binary channel.

Note that the Channel id text parameter is used in COMTRADE configuration filesas a channel identifier.

The recording always contains all binary channels of the disturbance recorder. Ifone of the binary channels is disabled, the recorded state of the channel iscontinuously FALSE and the state changes of the corresponding channel are notrecorded. The corresponding channel name for disabled binary channels in theCOMTRADE configuration file is Unused BI.

To enable or disable a binary channel of the disturbance recorder, the user can setthe Operation parameter of the corresponding binary channel to the values "on" or"off".

The states of manual triggering and periodic triggering are not included in therecording, but they create a state change to the Periodic triggering and Manualtriggering status parameters, which in turn create events.

The Recording started parameter can be used to control the indication LEDs of theIED. The output of the Recording started parameter is TRUE due to the triggeringof the disturbance recorder, until all the data for the corresponding recording isrecorded.

The IP number of the IED and the content of the Bay nameparameter are both included in the COMTRADE configuration filefor identification purposes.

8.2.3 ApplicationThe disturbance recorder is used for post-fault analysis and for verifying the correctoperation of protection IEDs and circuit breakers. It can record both analog andbinary signal information. The analog inputs are recorded as instantaneous valuesand converted to primary peak value units when the IED converts the recordings tothe COMTRADE format.



COMTRADE is the general standard format used in storingdisturbance recordings.

The binary channels are sampled once per task execution of the disturbancerecorder. The task execution interval for the disturbance recorder is the same as forthe protection functions. During the COMTRADE conversion, the digital statusvalues are repeated so that the sampling frequencies of the analog and binarychannels correspond to each other. This is required by the COMTRADE standard.

The disturbance recorder follows the 1999 version of theCOMTRADE standard and uses the binary data file format.

8.2.4 SettingsTable 527: Non-group general settings for disturbance recorder


5=off 1 1=on Disturbance

recorder on/off

Record length 10...500 fundamentalcycles

1 50 Size of therecording infundamentalcycles

Pre-trg length 0...100 % 1 50 Length of therecordingpreceding thetriggering

Operationmode

1=Saturation2=Overwrite

1 1 Operationmode of therecorder

Exclusion time 0...1 000 000 ms 1 0 The timeduring whichtriggerings ofsame type areignored

Storage rate 32, 16, 8 samples perfundamentalcycle

32 Storage rateof thewaveformrecording

Periodic trigtime

0...604 800 s 10 0 Time betweenperiodictriggerings

Stor. modeperiodic

0=Waveform1=Trend /cycle

1 0 Storage modefor periodictriggering

Stor. modemanual

0=Waveform1=Trend /cycle

1 0 Storage modefor manualtriggering



Table 528: Non-group analog channel settings for disturbance recorder


5=off 1 1=on Analog

channel isenabled ordisabled

Channelselection

0=Disabled,1=Io2=IL13=IL24=IL35=IoB6=IL1B7=IL2B8=IL3B9=Uo10=U111=U212=U313=UoB14=U1B15=U2B16=U3B17=CIo18=SI11)

19=SI21)

20=SU021=SU11)

22=SU21)

23=CIoB24=SI1B1)

25=SI2B1)

26=SUoB27=SU1B1)

28=SU2B1)

29=U1230=U2331=U3132=UL133=UL234=UL335=U12B36=U23B37=U31B38=UL1B39=UL2B40=UL3B41=U1T42=U2T43=U3T44=PD

0 0=Disabled Select thesignal to berecorded bythis channel.Applicablevalues for thisparameter areproductvariantdependent.Every productvariantincludes onlythe valuesthat areapplicable tothat particularvariant

Channel idtext

0 to 64characters,alphanumeric

DR analogchannel X

Identificationtext for theanalogchannel usedin theCOMTRADEformat




Parameter Values (Range) Unit Step Default DescriptionHigh triggerlevel

0.00...60.00 pu 0.01 10.00 High triggerlevel for theanalogchannel

Low triggerlevel

0.00...2.00 pu 0.01 0.00 Low triggerlevel for theanalogchannel

Storage mode 0=Waveform1=Trend /cycle

1 0 Storage modefor the analogchannel

1) Recordable values are available only in trend mode. In waveform mode, samples for this signal typeare constant zeroes. However, these signal types can be used to trigger the recorder on limitviolations of the corresponding analog channel.

Table 529: Non-group binary channel settings for disturbance recorder


5=off 1 5=off Binary

channel isenabled ordisabled

Level triggermode

1=Positive orRising2=Negative orFalling3=Both4=Leveltrigger off

1 1=Rising Level triggermode for thebinarychannel

Storage mode 0=Waveform1=Trend /cycle

1 0 Storage modefor the binarychannel

Channel idtext

0 to 64characters,alphanumeric

DR binarychannel X

Identificationtext for theanalogchannel usedin theCOMTRADEformat

Table 530: Control data for disturbance recorder

Parameter Values (Range) Unit Step Default DescriptionTrig recording 0=Cancel

1=Trig Trigger the

disturbancerecording

Clearrecordings

0=Cancel1=Clear

Clear allrecordingscurrently inmemory



8.2.5 Monitored dataTable 531: Monitored data for disturbance recorder

Parameter Values (Range) Unit Step Default DescriptionNumber ofrecordings

0...100 Number ofrecordingscurrently inmemory

Rem. amountof rec.

0...100 Remainingamount ofrecordingsthat fit into theavailablerecordingmemory,when currentsettings areused

Rec. memoryused

0...100 % Storage modefor the binarychannel

Time totrigger

0...604 800 s Timeremaining tothe nextperiodictriggering

8.2.6 Technical revision historyTable 532: RDRE Technical revision history

Technical revision ChangeB ChNum changed to EChNum (RADR's).

RADR9...12 added (Analog channel 9 -12).RBDR33...64 added (Binary channel 33 - 64).

C Enum update for Channel selection parameters(DR.RADRx.EChNum.setVal)Std. enum changes to Clear and Manual Trig

D Symbols in the Channel selection setting areupdated

8.3 Tap changer position indicator TPOSSLTC




Tap changer position indication TPOSSLTC TPOSM 84M




GUID-9FF20342-1B3C-45DB-8FB5-50389401AEF5 V2 EN


8.3.3 FunctionalityThe tap changer position indication function TPOSSLTC is used for transformertap position supervision. The binary inputs can be used for converting a binary-coded tap changer position to a tap position status indication. The X130 (RTD)card, available as an option, provides the RTD sensor information to be used andthe versatile analog inputs enabling the tap position supervision through mA.

There are three user-selectable conversion modes available for the 7–bit binaryinputs where MSB is used as the SIGN bit: the natural binary-coded boolean inputto the signed integer output, binary coded decimal BCD input to the signed integeroutput and binary reflected GRAY coded input to the signed integer output.

8.3.4 Operation principleThe function can be enabled and disabled with the Operation setting. Thecorresponding parameter values are "On" and "Off". When the function is disabled,the tap position quality information is changed accordingly. When the tap positioninformation is not available, it is recommended to disable this function with theOperation setting.

The operation of the tap changer position indication function can be describedusing a module diagram. All the modules in the diagram are explained in the nextsections.

GUID-DDA703D9-A4FF-41D8-9711-AC53A56B34E8 V2 EN




Tap position decoderWhen there is a wired connection to the TAP_POS connector, the correspondingtap changer position is decoded from the mA or RTD input. When there is no wiredconnection to the TAP_POS connector, the binary inputs are expected to be usedfor the tap changer position information. The tap changer position value andquality are internally shared to other functions. The value is available through theMonitored data view.

The function has three alternative user selectable operation modes: "NAT2INT","BCD2INT" and "GRAY2INT". The operation mode is selected with theOperation mode setting. Each operation mode can be used to convert a maximumof 6–bit coded input to an 8–bit signed short integer output. For less than 6–bitinput, for example 19 positions with 5 bits when the BCD coding is used, the restof the bits can be set to FALSE (0).

The operation mode "NAT2INT" is selected when the natural binary coding is usedfor showing the position of the transformer tap changer. The basic principle of thenatural binary coding is to calculate the sum of the bits set to TRUE (1). The LSBhas the factor 1. Each following bit has the previous factor multiplied by 2. This isalso called dual coding.

The operation mode "BCD2INT" is selected when the binary-coded decimalcoding is used for showing the position of the transformer tap changer. The basicprinciple with the binary-coded decimal coding is to calculate the sum of the bitsset to TRUE (1). The four bits nibble (BI3...BI0) have a typical factor to the naturalbinary coding. The sum of the values should not be more than 9. If the nibble sumis greater than 9, the tap position output validity is regarded as bad.

The operation mode “GRAY2INT” is selected when the binary-reflected Graycoding is used for showing the position of the transformer tap changer. The basicprinciple of the Gray coding is that only one actual bit changes value withconsecutive positions. This function is based on the common binary-reflected Graycode which is used with some tap changers. Changing the bit closest to the rightside bit gives a new pattern.

An additional separate input, SIGN_BIT, can be used for negative values. If thevalues are positive, the input is set to FALSE (0). If the SIGN_BIT is set to TRUE(1) making the number negative, the remaining bits are identical to those of thecoded positive number.

The tap position validity is set to good in all valid cases. The quality is set to bad ininvalid combinations in the binary inputs. For example, when the “BCD2INT”mode is selected and the input binary combination is “0001101”, the quality is setto bad. For negative values, when the SIGN_BIT is set to TRUE (1) and the inputbinary combination is “1011011”, the quality is set to bad.



Table 533: Truth table of the decoding modes

Inputs TAP_POS outputsSIGN_BIT

BI5 BI4 BI3 BI2 BI1 BI0 NAT2INT

BCD2INT

GRAY2INT

... ... ... ... ... ... ...

1 0 0 0 0 1 1 —3 —3 —2

1 0 0 0 0 1 0 —2 —2 —3

1 0 0 0 0 0 1 —1 —1 —1

0 0 0 0 0 0 0 0 0 0

0 0 0 0 0 0 1 1 1 1

0 0 0 0 0 1 0 2 2 3

0 0 0 0 0 1 1 3 3 2

0 0 0 0 1 0 0 4 4 7

0 0 0 0 1 0 1 5 5 6

0 0 0 0 1 1 0 6 6 4

0 0 0 0 1 1 1 7 7 5

0 0 0 1 0 0 0 8 8 15

0 0 0 1 0 0 1 9 9 14

0 0 0 1 0 1 0 10 9 12

0 0 0 1 0 1 1 11 9 13

0 0 0 1 1 0 0 12 9 8

0 0 0 1 1 0 1 13 9 9

0 0 0 1 1 1 0 14 9 11

0 0 0 1 1 1 1 15 9 10

0 0 1 0 0 0 0 16 10 31

0 0 1 0 0 0 1 17 11 30

0 0 1 0 0 1 0 18 12 28

0 0 1 0 0 1 1 19 13 29

0 0 1 0 1 0 0 20 14 24

0 0 1 0 1 0 1 21 15 25

0 0 1 0 1 1 0 22 16 27

0 0 1 0 1 1 1 23 17 26

0 0 1 1 0 0 0 24 18 16

0 0 1 1 0 0 1 25 19 17

0 0 1 1 0 1 0 26 19 19

0 0 1 1 0 1 1 27 19 18

0 0 1 1 1 0 0 28 19 23

0 0 1 1 1 0 1 29 19 22

0 0 1 1 1 1 0 30 19 20

0 0 1 1 1 1 1 31 19 21




Inputs TAP_POS outputs0 1 0 0 0 0 0 32 20 63

0 1 0 0 0 0 1 33 21 62

0 1 0 0 0 1 0 34 22 60

0 1 0 0 0 1 1 35 23 61

0 1 0 0 1 0 0 36 24 56

... ... ... ... ... ... ...

8.3.5 ApplicationTPOSSLTC provides tap position information for other functions as a signedinteger value that can be fed to the tap position input.

The position information of the tap changer can be coded in various methods formany applications, for example, the differential protection algorithms. In thisfunction, the binary inputs in the transformer terminal connector are used as inputsto the function. The coding method can be chosen by setting the mode parameter.The available coding methods are BCD, Gray and Natural binary coding. Since thenumber of binary inputs are limited to seven, the coding functions are limited toseven bits including the sign bit and thus the six bits are used in the codingfunctions. The position limits for the tap positions at BCD, Gray and Naturalbinary coding are ±39, ±63 and ±63 respectively.

In this example, the transformer tap changer position indication is wired as a mAsignal from the corresponding measuring transducer. The position indication isconnected to input 1 (AI_VAL1) of the X130 (RTD) card. The tap changeroperating range from the minimum to maximum turns of the tap and acorresponding mA signal for the tap position are set in XRGGIO130. Since thevalues of the XRGGIO130 outputs are floating point numbers, the float to integer(T_F32_INT8) conversion is needed before the tap position information can be fedto TPOSSLTC. When there is a wired connection to the TAP_POS connector, thecorresponding tap changer position is seen as the TAP_POS output value that is fedto other functions, for example, OLATCC1. When there is no wired connection tothe TAP_POS connector, the binary inputs are expected to be used for the tapchanger position information.

TPOSSLTC

BI1BI2BI3BI4BI5SIGN_BITTAP_POS

BI0

F32 INT8T_F32_INT8

AI_VAL1

GUID-0F8FDC38-827F-48F2-AC02-499CD3B121D7 V1 EN

Figure 321: RTD/analog input configuration example



8.3.6 SignalsTable 534: TPOSSLTC Input signals

Name Type Default DescriptionBI0 BOOLEAN 0=False Binary input 1

BI1 BOOLEAN 0=False Binary input 2





SIGN_BIT BOOLEAN 0=False Binary input sign bit

TAP_POS INT8 0 Tap position indication

8.3.7 SettingsTable 535: TPOSSLTC Non group settings



Operation mode 1=NAT2INT2=BCD2INT3=GRAY2INT

2=BCD2INT Operation mode selection

8.3.8 Monitored data

8.3.9 Technical dataTable 536: TPOSSLTC Technical data

Descrpition ValueResponse time for binary inputs Typical 100 ms

8.3.10 Technical revision historyTable 537: TPOSSLTC Technical revision history

Technical revision ChangeB Added new input TAP_POS



Section 9 Control functions

9.1 Circuit breaker control CBXCBR, Disconnectorcontrol DCXSWI and Earthing switch controlESXSWI




Circuit breaker control CBXCBR I<->O CB I<->O CB

Disconnector control DCXSWI I<->O DCC I<->O DCC

Earthing switch control ESXSWI I<->O ESC I<->O ESC


A071284 V3 EN

GUID-87017F8B-A03A-409C-8707-E721A1B0DE3E V1 EN

GUID-91FB6354-B7B0-46B4-9975-BE2769B97902 V1 EN


1MRS756887 G Section 9Control functions


9.1.3 FunctionalityThe CBXCBR, DCXSWI and ESXSWI are intended for circuit breaker,disconnector and earthing switch control and status information purposes. Thesefunctions execute commands and evaluate block conditions and different timesupervision conditions. The functions perform an execution command only if allconditions indicate that a switch operation is allowed. If erroneous conditionsoccur, the functions indicate an appropriate cause value. The functions aredesigned according to the IEC 61850-7-4 standard with logical nodes CILO, CSWIand XSWI / XCBR.

The circuit breaker, disconnector and earthing switch control functions have anoperation counter for closing and opening cycles. The counter value can be readand written remotely from the place of operation or via LHMI.

9.1.4 Operation principle

Status indication and validity checkThe object state is defined by two digital inputs, POSOPEN and POSCLOSE, whichare also available as outputs OPENPOS and CLOSEPOS together with the OKPOSinformation. The debouncing and short disturbances in an input are eliminated byfiltering. The binary input filtering time can be adjusted separately for each digitalinput used by the function block. The validity of the digital inputs that indicate theobject state is used as additional information in indications and event logging. Thereporting of faulty or intermediate position of the apparatus occurs after the Eventdelay setting, assuming that the circuit breaker is still in a corresponding state.

Table 538: Status indication

Status (POSITION) POSOPEN/OPENPOS POSCLOSE/CLOSEPOS

OKPOS

1=Open 1=True 0=False 1=True

2=Closed 0=False 1=True 1=True

3=Faulty/Bad (11) 1=True 1=True 0=False

0=Intermediate (00) 0=False 0=False 0=False

BlockingCBXCBR, DCXSWI and ESXSWI have a blocking functionality to prevent humanerrors that can cause injuries to the operator and damages to the system components.

The basic principle for all blocking signals is that they affect the commands ofother clients: the operator place and protection and autoreclosing functions, forexample. There are two blocking principles.

Section 9 1MRS756887 GControl functions


• Enabling the opening command: the function is used to block the operation ofthe opening command. This block signal also affects the OPEN input ofimmediate command.

• Enabling the closing command: the function is used to block the operation ofthe closing command. This block signal also affects the CLOSE input ofimmediate command.

The ITL_BYPASS input is used if the interlocking functionality needs to bebypassed. When INT_BYPASS is TRUE, the apparatus control is made possibleby discarding the ENA_OPEN and ENA_CLOSE input states. However, theBLK_OPEN and BLK_CLOSE input signals are not bypassed with the interlockingbypass functionality since they always have the higher priority.

Table 539: Interlocking conditions for enabling the closing (opening) command

Inputs OutputsINT_BYPASS ENA_CLOSE

(ENA_OPEN)BLK_CLOSE(BLK_OPEN)

CLOSE_ENAD(OPEN_ENAD)

0 = False 0 = False 0 = False 0 = False

0 = False 0 = False 1 = True 0 = False

0 = False 1 = True 0 = False 1 = True

0 = False 1 = True 1 = True 0 = False

1 = True 0 = False 0 = False 1 = True

1 = True 0 = False 1 = True 0 = False

1 = True 1 = True 0 = False 1 = True

1 = True 1 = True 1 = True 0 = False

Opening and closing operationsThe corresponding opening and closing operations are available viacommunication, binary inputs or LHMI commands. As a prerequisite for controlcommands, there are enabling and blocking functionalities for both opening andclosing commands. If the control command is executed against the blocking or ifthe enabling of the corresponding command is not valid, CBXCBR, DCXSWI andESXSWI generate an error message.

Opening and closing pulse widthsThe pulse width type can be defined with the Adaptive pulse setting. The functionprovides two modes to characterize the opening and closing pulse widths. Whenthe Adaptive pulse is set to “TRUE”, it causes a variable pulse width, which meansthat the output pulse is deactivated when the object state shows that the apparatushas entered the correct state. If apparatus fails to enter the correct state, the outputpulse is deactivated after the set Operation timeout setting, and an error message isdisplayed. When the Adaptive pulse is set to “FALSE”, the functions always usethe maximum pulse width, defined by the user-configurable Pulse length setting.The Pulse length setting is the same for both the opening and closing commands.



When the apparatus already is in the right position, the maximum pulse length isgiven.

The Pulse length setting does not affect the length of the trip pulse.

Control methodsThe command execution mode can be set with the Control model setting. Thealternatives for command execution are direct control and secured object control,which can be used to secure controlling.

The secured object control SBO is an important feature of the communicationprotocols that support horizontal communication, because the commandreservation and interlocking signals can be transferred with a bus. All securedcontrol operations require two-step commands: a selection step and an executionstep. The secured object control is responsible for the several tasks.

• Command authority: ensures that the command source is authorized to operatethe object

• Mutual exclusion: ensures that only one command source at a time can controlthe object

• Interlocking: allows only safe commands• Execution: supervises the command execution• Command canceling: cancels the controlling of a selected object.

In direct operation, a single message is used to initiate the control action of aphysical device. The direct operation method uses less communication networkcapacity and bandwidth than the SBO method, because the procedure needs fewermessages for accurate operation.



A070878 V2 EN

Figure 323: Control procedure in the SBO method

9.1.5 ApplicationIn the field of distribution and sub-transmission automation, reliable control andstatus indication of primary switching components both locally and remotely is in asignificant role. They are needed especially in modern remotely controlledsubstations.

Control and status indication facilities are implemented in the same package withCBXCBR, DCXSWI and ESXSWI. When primary components are controlled inthe energizing phase, for example, the correct execution sequence of the controlcommands must be ensured. This can be achieved, for example, with interlockingbased on the status indication of the related primary components. The interlockingon the substation level can be applied using the IEC61850 GOOSE messagesbetween feeders.



A070879 V2 EN

Figure 324: Status indication-based interlocking via the GOOSE messaging

9.1.6 SignalsTable 540: CBXCBR Input signals

Name Type Default DescriptionENA_OPEN BOOLEAN 1=True Enables opening

ENA_CLOSE BOOLEAN 1=True Enables closing

BLK_OPEN BOOLEAN 0=False Blocks opening

BLK_CLOSE BOOLEAN 0=False Blocks closing

ITL_BYPASS BOOLEAN 0=False Discards ENA_OPEN and ENA_CLOSEinterlocking when TRUE

AU_OPEN BOOLEAN 0=False Input signal used to open the breaker1)

AU_CLOSE BOOLEAN 0=False Input signal used to close the breaker1)

POSOPEN BOOLEAN 0=False Signal for open position of apparatus from I/O1)

POSCLOSE BOOLEAN 0=False Signal for closed position of apparatus from I/O1)

1) Not available for monitoring

Table 541: DCXSWI Input signals







Name Type Default DescriptionBLK_CLOSE BOOLEAN 0=False Blocks closing


EXE_OP BOOLEAN 0=False Executes the command for open direction

EXE_CL BOOLEAN 0=False Executes the command for close direction

OPENPOS BOOLEAN 0=False Apparatus open position

CLOSEPOS BOOLEAN 0=False Apparatus closed position

Table 542: ESXSWI Input signals




BLK_CLOSE BOOLEAN 0=False Blocks closing


EXE_OP BOOLEAN 0=False Executes the command for open direction

EXE_CL BOOLEAN 0=False Executes the command for close direction

OPENPOS BOOLEAN 0=False Apparatus open position

CLOSEPOS BOOLEAN 0=False Apparatus closed position

Table 543: CBXCBR Output signals

Name Type DescriptionSELECTED BOOLEAN Object selected

EXE_OP BOOLEAN Executes the command for open direction

EXE_CL BOOLEAN Executes the command for close direction

OPENPOS BOOLEAN Apparatus open position

CLOSEPOS BOOLEAN Apparatus closed position

OKPOS BOOLEAN Apparatus position is ok

OPEN_ENAD BOOLEAN Opening is enabled based on the input status

CLOSE_ENAD BOOLEAN Closing is enabled based on the input status

Table 544: DCXSWI Output signals









Name Type DescriptionOKPOS BOOLEAN Apparatus position is ok



Table 545: ESXSWI Output signals









9.1.7 SettingsTable 546: CBXCBR Non group settings


5=off 1=on Operation mode on/off

Select timeout 10000...300000 ms 10000 60000 Select timeout in ms

Pulse length 10...60000 ms 1 100 Open and close pulse length

Operation counter 0...10000 0 Breaker operation cycles

Control model 0=status-only1=direct-with-normal-security4=sbo-with-enhanced-security

4=sbo-with-enhanced-security

Select control model

Adaptive pulse 0=False1=True

1=True Stop in right position

Event delay 0...10000 ms 1 100 Event delay of the intermediate position

Operation timeout 10...60000 ms 500 Timeout for negative termination

Table 547: DCXSWI Non group settings









Parameter Values (Range) Unit Step Default DescriptionControl model 0=status-only

1=direct-with-normal-security4=sbo-with-enhanced-security







Table 548: ESXSWI Non group settings






Control model 0=status-only1=direct-with-normal-security4=sbo-with-enhanced-security







9.1.8 Monitored dataTable 549: CBXCBR Monitored data

Name Type Values (Range) Unit DescriptionPOSITION Dbpos 0=intermediate

1=open2=closed3=faulty

Apparatus positionindication

Table 550: DCXSWI Monitored data






Table 551: ESXSWI Monitored data




9.1.9 Technical revision historyTable 552: CBXCBR Technical revision history

Technical revision ChangeB Interlocking bypass input (ITL_BYPASS) and

opening enabled (OPEN_ENAD)/closing enabled(CLOSE_ENAD) outputs added. ITL_BYPASSbypasses the ENA_OPEN and ENA_CLOSE states.

9.2 Disconnector position indicator DCSXSWI andearthing switch indication ESSXSWI




Disconnector position indicator DCSXSWI I<->O DC I<->O DC

Earthing switch indication ESSXSWI I<->O ES I<->O ES


A071280 V2 EN


A071282 V2 EN




9.2.3 FunctionalityThe functions DCSXSWI and ESSXSWI indicate remotely and locally the open,close and undefined states of the disconnector and earthing switch. Thefunctionality of both is identical, but each one is allocated for a specific purposevisible in the function names. For example, the status indication of disconnectors orcircuit breaker truck can be monitored with the DCSXSWI function.

The functions are designed according to the IEC 61850-7-4 standard with thelogical node XSWI.

9.2.4 Operation principle

Status indication and validity checkThe object state is defined by the two digital inputs POSOPEN and POSCLOSE.The debounces and short disturbances in an input are eliminated by filtering. Thebinary input filtering time can be adjusted separately for each digital input used bythe function block. The validity of digital inputs that indicate the object state isused as additional information in indications and event logging.

Table 553: Status indication

State OPEN CLOSEOpen ON OFF

Close OFF ON

Bad/Faulty 11 ON ON

Intermediate 00 OFF OFF

9.2.5 ApplicationIn the field of distribution and sub-transmission automation, the reliable controland status indication of primary switching components both locally and remotely isin a significant role. These features are needed especially in modern remotecontrolled substations. The application area of DCSXSWI and ESSXSWI functionscovers remote and local status indication of, for example, disconnectors, air-breakswitches and earthing switches, which represent the lowest level of powerswitching devices without short-circuit breaking capability.

9.2.6 SignalsTable 554: DCSXSWI Input signals

Name Type Default DescriptionPOSOPEN BOOLEAN 0=False Signal for open position of apparatus from I/O1)





Table 555: ESSXSWI Input signals

Name Type Default DescriptionPOSOPEN BOOLEAN 0=False Signal for open position of apparatus from I/O1)



Table 556: DCSXSWI Output signals

Name Type DescriptionOPENPOS BOOLEAN Apparatus open position



Table 557: ESSXSWI Output signals

Name Type DescriptionOPENPOS BOOLEAN Apparatus open position



9.2.7 SettingsTable 558: DCSXSWI Non group settings

Parameter Values (Range) Unit Step Default DescriptionEvent delay 0...10000 ms 1 100 Event delay of the intermediate position

Table 559: ESSXSWI Non group settings

Parameter Values (Range) Unit Step Default DescriptionEvent delay 0...10000 ms 1 100 Event delay of the intermediate position

9.2.8 Monitored dataTable 560: DCSXSWI Monitored data






Table 561: ESSXSWI Monitored data




9.3 Synchronism and energizing check SECRSYN

9.3.1 IdentificationFunctional description IEC 61850



Synchronism and energizing check SECRSYN SYNC 25


GUID-9270E059-ED17-4355-90F0-3345E1743464 V2 EN


9.3.3 FunctionalityThe synchrocheck function SECRSYN checks the condition across the circuitbreaker from separate power system parts and gives the permission to close thecircuit breaker. SECRSYN includes the functionality of synchrocheck andenergizing check.

Asynchronous operation mode is provided for asynchronously running systems.The main purpose of the asynchronous operation mode is to provide a controlledclosing of circuit breakers when two asynchronous systems are connected.

The synchrocheck operation mode checks that the voltages on both sides of thecircuit breaker are perfectly synchronized. It is used to perform a controlledreconnection of two systems which are divided after islanding and it is also used toperform a controlled reconnection of the system after reclosing.

The energizing check function checks that at least one side is dead to ensure thatclosing can be done safely.



The function contains a blocking functionality. It is possible to block functionoutputs and timers if desired.


The SECRSYN function has two parallel functionalities, the synchrocheck andenergizing check functionality. The operation of the synchronism and energizingcheck function can be described using a module diagram. All the modules in thediagram are explained in the next sections.

Energizing check

Synchro check

GUID-FE07029C-C6C1-4BA7-9F8E-CACE86D0A9BD V2 EN


The Synchro check function can operate either with the U_AB or U_A voltages.The selection of used voltages is defined with the VT connection setting of the linevoltage general parameters.

Energizing checkThe Energizing check function checks the energizing direction. Energizing isdefined as a situation where a dead network part is connected to an energizedsection of the network. The conditions of the network sections to be controlled bythe circuit breaker, that is, which side has to be live and which side dead, aredetermined by the setting. A situation where both sides are dead is possible as well.The actual value for defining the dead line or bus is given with the Dead bus valueand Dead line value settings. Similarly, the actual values of live line or bus aredefined with the Live bus value and Live line value settings.

Table 562: Live dead mode of operation under which switching can be carried out

Live dead mode DescriptionBoth Dead Both line and bus de-energized

Live L, Dead B Bus de-energized and line energized

Dead L, Live B Line de-energized and bus energized




Live dead mode DescriptionDead Bus, L Any Both line and bus de-energized or bus de-

energized and line energized

Dead L, Bus Any Both line and bus de-energized or line de-energized and bus energized

One Live, Dead Bus de-energized and line energized or line de-energized and bus energized

Not Both Live Both line and bus de-energized or bus de-energized and line energized or line de-energized and bus energized

When the energizing direction corresponds to the settings, the situation has to beconstant for a time set with the Energizing time setting before the circuit breakerclosing is permitted. The purpose of this time delay is to ensure that the dead sideremains de-energized and also that the situation is not caused by a temporaryinterference. If the conditions do not persist for a specified operation time, thetimer is reset and the procedure is restarted when the conditions allow. The circuitbreaker closing is not permitted if the measured voltage on the live side is greaterthan the set value of Max energizing V.

The measured energized state is available as a monitored data valueENERG_STATE and as four function outputs LLDB (live line / dead bus), LLLB(live line / live bus), DLLB (dead line / live bus) and DLDB (dead line / dead bus),of which only one can be active at a time. It is also possible that the measuredenergized state indicates “Unknown” if at least one of the measured voltages isbetween the limits set with the dead and live settings parameters.

Synchro checkThe Synchro check function measures the difference between the line voltage andbus voltage. The function permits the closing of the circuit breaker when thefollowing conditions are simultaneously fulfilled.

• The measured line and bus voltages are higher than the set values of Live busvalue and Live line value (ENERG_STATE equals to "Both Live").

• The measured bus and line frequency are both within the range of 95 to 105percent of the value of fn.

• The measured voltages for the line and bus are less than the set value of Maxenergizing V.

In case Syncro check mode is set to "Syncronous", the additional conditions mustbe fulfilled.

• In the synchronous mode, the closing is attempted so that the phase differenceat closing is close to zero.

• The synchronous mode is only possible when the frequency slip is below 0.1percent of the value of fn.

• The voltage difference must not exceed the 1 percent of the value of Un.



In case Syncro check mode is set to “Asyncronous”, the additional conditions mustbe fulfilled.

• The measured difference of the voltages is less than the set value of Differencevoltage.

• The measured difference of the phase angles is less than the set value ofDifference angle.

• The measured difference in frequency is less than the set value of Frequencydifference.

• The estimated breaker closing angle is decided to be less than the set value ofDifference angle.

Dead line or bus value

Live line or bus value

Difference angle

U_Bus

U_LineDifference voltage

fU_Bus fU_Line

Frequency[Hz]

f = abs(fU_Bus - fU_Line)

Rated frequency

Frequency deviation

= U_Bus - U_Line Difference frequency

GUID-191F6C44-7A67-4277-8AD1-9711B535F1E1 V2 EN

Figure 329: Conditions to be fulfilled when detecting synchronism betweensystems

When the frequency, phase angle and voltage conditions are fulfilled, the durationof the synchronism conditions is checked so as to ensure that they are still metwhen the condition is determined on the basis of the measured frequency and phasedifference. Depending on the circuit breaker and the closing system, the delay fromthe moment the closing signal is given until the circuit breaker finally closes isabout 50 - 250 ms. The selected Closing time of CB informs the function how longthe conditions have to persist. The Synchro check function compensates for themeasured slip frequency and the circuit breaker closing delay. The phase angleadvance is calculated continuously with the formula.



Closing angle = ∠ − ∠( )° + −( )× +( )× °( )U U f f T TBus Line Bus line CB PL 360

GUID-48292FC2-C00C-4166-BCAD-FFC77D7F196B V1 EN (Equation 76)

φU_BUS Measured bus voltage phase angle

φU_LINE Measured line voltage phase angle

fU_BUS Measured bus frequency

fU_LINE Measured line frequency

TCB Total circuit breaker closing delay, including the delay of the IED output contacts definedwith the Closing time of CB setting parameter value

The closing angle is the estimated angle difference after the breaker closing delay.

The Minimum Syn time setting time can be set, if required, to demand the minimumtime within which conditions must be simultaneously fulfilled before theSYNC_OK output is activated.

The measured voltage, frequency and phase angle difference values between thetwo sides of the circuit breaker are available as monitored data valuesU_DIFF_MEAS, FR_DIFF_MEAS and PH_DIFF_MEAS. Also, the indications ofthe conditions that are not fulfilled and thus preventing the breaker closingpermission are available as monitored data values U_DIFF_SYNC,PH_DIF_SYNC and FR_DIFF_SYNC. These monitored data values are updatedonly when the Synchro check is enabled with the Synchro check mode setting andthe measured ENERG_STATE is "Both Live".

Continuous modeThe continuous mode is activated by setting the parameter Control mode to"Continuous". In the continuous control mode, Synchro check is continuouslychecking the synchronism. When synchronism is detected (according to thesettings), the SYNC_OK output is set to TRUE (logic '1') and it stays TRUE as longas the conditions are fulfilled. The command input is ignored in the continuouscontrol mode. The mode is used for situations where Synchro check only gives thepermission to the control block that executes the CB closing.

SECRSYN CBXCBR I

Closing permission

Closing command

GUID-A9132EDC-BFAB-47CF-BB9D-FDE87EDE5FA5 V2 EN

Figure 330: A simplified block diagram of the Synchro check function in thecontinuous mode operation



Command modeIf Control mode is set to "Command", the purpose of the Synchro checkfunctionality in the command mode is to find the instant when the voltages on bothsides of the circuit breaker are in synchronism. The conditions for synchronism aremet when the voltages on both sides of the circuit breaker have the same frequencyand are in phase with a magnitude that makes the concerned busbars or lines suchthat they can be regarded as live.

In the command mode operation, an external command signal CL_COMMAND,besides the normal closing conditions, is needed for delivering the closing signal.In the command control mode operation, the Synchro check function itself closesthe breaker via the SYNC_OK output when the conditions are fulfilled. In this case,the control function block delivers the command signal to close the Synchro checkfunction for the releasing of a closing signal pulse to the circuit breaker. If theclosing conditions are fulfilled during a permitted check time set with MaximumSyn time, the Synchro check function delivers a closing signal to the circuit breakerafter the command signal is delivered for closing.

SECRSYNCBXCBR I

Closing request

Closing command

GUID-820585ED-8AED-45B1-8FC2-2CEE7727A65C V2 EN

Figure 331: A simplified block diagram of SECRSYN in the command modeoperation

The closing signal is delivered only once for each activated external closingcommand signal. The pulse length of the delivered closing is set with the Closepulse setting.



t = Close pulse

GUID-0D9A1A7F-58D1-4081-B974-A3CE10DEC5AF V2 EN

Figure 332: Determination of the pulse length of the closing signal

In the command control mode operation, there are alarms for a failed closingattempt (CL_FAIL_AL) and for a command signal that remains active too long(CMD_FAIL_AL).

If the conditions for closing are not fulfilled within the set time of Maximum Syntime, a failed closing attempt alarm is given. The CL_FAIL_AL alarm outputsignal is pulse-shaped and the pulse length is 500 ms. If the external commandsignal is removed too early, that is, before conditions are fulfilled and the closingpulse is given, the alarm timer is reset.

Maximum Syn time

GUID-FA8ADA22-6A90-4637-AA1C-714B1D0DD2CF V2 EN

Figure 333: Determination of the checking time for closing

The control module receives information about the circuit breaker status and thus isable to adjust the command signal to be delivered to the Synchro check function. Ifthe external command signal CL_COMMAND is kept active longer thannecessary, CMD_FAIL_AL alarm output is activated. The alarm indicates that the



control module has not removed the external command signal after the closingoperation. To avoid unnecessary alarms, the duration of the command signalshould be set in such a way that the maximum length of the signal is always belowMaximum Syn time + 5s.

Close pulse

Maximum Syn time

5sGUID-4DF3366D-33B9-48B5-8EB4-692D98016753 V2 EN

Figure 334: Determination of the alarm limit for a still-active command signal

Closing is permitted during Maximum Syn time, starting from the moment theexternal command signal CL_COMMAND is activated. The CL_COMMAND inputmust be kept active for the whole time that the closing conditions are waited to befulfilled. Otherwise, the procedure is cancelled. If the closing-command conditionsare fulfilled during Maximum Syn time, a closing pulse is delivered to the circuitbreaker. If the closing conditions are not fulfilled during the checking time, thealarm CL_FAIL_AL is activated as an indication of a failed closing attempt. Theclosing pulse is not delivered if the closing conditions become valid after MaximumSyn time has elapsed. The closing pulse is delivered only once for each activatedexternal command signal, and a new closing-command sequence cannot be starteduntil the external command signal is reset and reactivated again. TheSYNC_INPRO output is active when the closing-command sequence is in progressand it is reset when the CL_COMMAND input is reset or Maximum Syn time has elapsed.

Bypass modeSECRSYN can be set into bypass mode by setting the parameters Synchro checkmode and Energizing check mode to "Off" or alternatively, by activating theBYPASS input.

In the bypass mode, the closing conditions are always considered to be fulfilled bythe SECRSYN function. Otherwise, the operation is similar to the normal mode.



Voltage angle difference adjustmentIn application where the power transformer is located between the voltagemeasurement and the vector group connection gives phase difference to thevoltages between the high and low-voltage sides, the angle adjustment can be usedto meet synchronism.

The vector group of the power transformer is defined with clock numbers, wherethe value of the hour pointer defines the low voltage-side phasor and the high voltage-side phasor is always fixed to the clock number 12, which is same as zero. Theangle between clock numbers is 30 degrees. When comparing phase angles, theU_BUS input is always the reference. This means that when the Yd11 powertransformer is used, the low voltage-side voltage phasor leads by 30 degrees or lagsby 330 degrees the high voltage-side phasor. The rotation of the phasors iscounterclockwise.

The generic rule is that a low voltage-side phasor lags the high voltage-side phasorby clock number * 30º. This is called angle difference adjustment and can be setfor SECRSYN with the Phase shift setting.

9.3.5 ApplicationThe main purpose of the synchrocheck function is to provide control over theclosing of the circuit breakers in power networks to prevent the closing if theconditions for synchronism are not detected. This function is also used to preventthe reconnection of two systems which are divided after islanding and a three-polereclosing.

The Synchro check function block includes both the synchronism check functionand the energizing function to allow closing when one side of the breaker is dead.

Network and the generator running in parallel with the network are connectedthrough the line AB. When a fault occurs between A and B, the IED protectionopens the circuit breakers A and B, thus isolating the faulty section from thenetwork and making the arc that caused the fault extinguish. The first attempt torecover is a delayed autoreclosure made a few seconds later. Then, the autoreclosefunction DARREC gives a command signal to the synchrocheck function to closethe circuit breaker A. SECRSYN performs an energizing check, as the line AB is de-energized (U_BUS> Live bus value, U_LINE< Dead line value). After verifyingthe line AB is dead and the energizing direction is correct, the IED energizes theline (U_BUS -> U_LINE) by closing the circuit breaker A. The PLC of the powerplant discovers that the line has been energized and sends a signal to the othersynchrocheck function to close the circuit breaker B. Since both sides of the circuitbreaker B are live (U_BUS > Live bus value, U_LINE > Live bus value), thesynchrocheck function controlling the circuit breaker B performs a synchrocheckand, if the network and the generator are in synchronism, closes the circuit breaker.



G

SECRSYN

DARREC

SECRSYN

PLC

A B

U_Bus U_BusU_Line U_Line

GUID-27A9936F-0276-47A1-B646-48E336FDA95C V2 EN

Figure 335: Synchrocheck function SECRSYN checking energizing conditionsand synchronism

ConnectionsA special attention is paid to the connection of the IED. Furthermore it is checkedthat the primary side wiring is correct.

A faulty wiring of the voltage inputs of the IED causes a malfunction in thesynchrocheck function. If the wires of an energizing input have changed places, thepolarity of the input voltage is reversed (180°). In this case, the IED permits thecircuit breaker closing in a situation where the voltages are in opposite phases. Thiscan damage the electrical devices in the primary circuit. Therefore, it is extremelyimportant that the wiring from the voltage transformers to the terminals on the rearof the IED is consistent regarding the energizing inputs U_BUS (bus voltage) andU_LINE (line voltage).

The wiring should be verified by checking the reading of the phase differencemeasured between the U_BUS and U_LINE voltages. The phase differencemeasured by the IED has to be close to zero within the permitted accuracytolerances. The measured phase differences are indicated in the LHMI. At the sametime, it is recommended to check the voltage difference and the frequencydifferences presented in the monitored data view. These values should be withinthe permitted tolerances, that is, close to zero.

Figure 336 shows an example where the synchrocheck is used for the circuitbreaker closing between a busbar and a line. The phase-to-phase voltages aremeasured from the busbar and also one phase-to-phase voltage from the line ismeasured.



L1

L3

U1

U2

U3

U0

U1b

U12

L2

Relay program

U_LINE

U_BUS

SECRSYNU_BUSU_LINE

BYPASS

SYNC_INPROSYNC_OK

CL_FAIL_ALCMD_FAIL_AL

CL_COMMAND

BLOCK ENERG_STATE

GUID-DE29AFFC-9769-459B-B52C-4C11DC37A583 V2 EN

Figure 336: Connection of voltages for the IED and signals used in synchrocheck

9.3.6 SignalsTable 563: SECRSYN Input signals

Name Type Default DescriptionU_BUS SIGNAL 0 Busbar voltage

U_LINE SIGNAL 0 Line voltage

CL_COMMAND BOOLEAN 0=False External closing request

BYPASS BOOLEAN 0=False Request to bypass synchronism check andvoltage check

BLOCK BOOLEAN 0=False Blocking signal of the synchro check and voltagecheck function

Table 564: SECRSYN Output signals

Name Type DescriptionSYNC_INPRO BOOLEAN Synchronizing in progress

SYNC_OK BOOLEAN Systems in synchronism

CL_FAIL_AL BOOLEAN CB closing failed

CMD_FAIL_AL BOOLEAN CB closing request failed

LLDB BOOLEAN Live Line, Dead Bus

LLLB BOOLEAN Live Line, Live Bus

DLLB BOOLEAN Dead Line, Live Bus

DLDB BOOLEAN Dead Line, Dead Bus



9.3.7 SettingsTable 565: Synchronism and energizing check (SECRSYN) main settings

Parameter Values (Range) Unit Step Default DescriptionLive dead mode -1=Off

1=Both Dead2=Live L, Dead B3=Dead L, Live B4=Dead Bus, L Any5=Dead L, Bus Any6=One Live, Dead7=Not Both Live

1=Both Dead Energizing checkmode

Difference voltage 0.01...0.50 xUn 0.01 0.05 Maximum voltagedifference limit

Difference frequency 0.001...0.100 xFn 0.001 0.001 Maximum frequencydifference limit

Difference angle 5...90 deg 1 5 Maximum angledifference limit

Synchrocheck mode 1=Off2=Synchronous3=Asynchronous

2=Synchronous Synchrocheckoperation mode

Control mode 1=Continuous2=Command

1=Continuous Selection of thesynchrocheckcommand orcontinuous controlmode

Dead line value 0.1...0.8 xUn 0.1 0.2 Voltage low-limit linefor energizing check

Live line value 0.2...1.0 xUn 0.1 0.5 Voltage high-limitline for energizingcheck

Close pulse 200...60000 ms 10 200 Breaker-closingpulse duration

Max energizing V 0.50...1.15 xUn 0.01 1.05 Maximum voltagefor energizing

Phase shift -180...180 deg 1 180 Correction of phasedifference betweenmeasured U_BUSand U_LINE

Minimum Syn time 0...60000 ms 10 0 Minimum time toaccept synchronizing

Maximum Syn time 100...6000000 ms 10 2000 Maximum time toaccept synchronizing

Energizing time 100...60000 ms 10 100 Time delay forenergizing check

Closing time of CB 40...250 ms 10 60 Closing time of thebreaker



9.3.8 Monitored dataTable 566: SECRSYN Monitored data

Name Type Values (Range) Unit DescriptionENERG_STATE Enum 0=Unknown

1=Both Live2=Live L, Dead B3=Dead L, Live B4=Both Dead

Energization state ofLine and Bus

U_DIFF_MEAS FLOAT32 0.00...1.00 xUn Calculated voltageamplitude difference

FR_DIFF_MEAS FLOAT32 0.000...0.100 xFn Calculated voltagefrequency difference

PH_DIFF_MEAS FLOAT32 0.00...180.00 deg Calculated voltagephase angle difference

U_DIFF_SYNC BOOLEAN 0=False1=True

Voltage difference out oflimit for synchronizing

PH_DIF_SYNC BOOLEAN 0=False1=True

Phase angle differenceout of limit forsynchronizing

FR_DIFF_SYNC BOOLEAN 0=False1=True

Frequency difference outof limit for synchronizing

SECRSYN Enum 1=on2=blocked3=test4=test/blocked5=off

Status

9.3.9 Technical dataTable 567: SECRSYN Technical data


measured: fn ±1 Hz

Voltage: ±3.0% of the set value or ±0.01 x UnFrequency: ±10 mHzPhase angle: ±3°

Reset time < 50 ms





9.4 Autoreclosing DARREC

9.4.1 IdentificationFunction description IEC 61850 logical

node nameIEC 60617identification


Autoreclosing DARREC O-->I 79


A070836 V3 EN


9.4.3 FunctionalityAbout 80 to 85 percent of faults in the MV overhead lines are transient andautomatically cleared with a momentary de-energization of the line. The rest of thefaults, 15 to 20 percent, can be cleared by longer interruptions. The de-energizationof the fault location for a selected time period is implemented through automaticreclosing, during which most of the faults can be cleared.

In case of a permanent fault, the automatic reclosing is followed by final tripping.A permanent fault must be located and cleared before the fault location can be re-energized.

The auto-reclose function AR can be used with any circuit breaker suitable for auto-reclosing. The function provides five programmable auto-reclose shots which canperform one to five successive auto-reclosings of desired type and duration, forinstance one high-speed and one delayed auto-reclosing.

When the reclosing is initiated with starting of the protection function, the auto-reclose function can execute the final trip of the circuit breaker in a short operatetime, provided that the fault still persists when the last selected reclosing has beencarried out.



9.4.3.1 Protection signal definition

The Control line setting defines which of the initiation signals are protection startand trip signals and which are not. With this setting, the user can distinguish theblocking signals from the protection signals. The Control line setting is a bit mask,that is, the lowest bit controls the INIT_1 line and the highest bit the INIT_6line. Some example combinations of the Control line setting are as follows:

Table 568: Control line setting definition

Control linesetting

INIT_1 INIT_2DEL_INIT_2

INIT_3DEL_INIT_3

INIT_4DEL_INIT_4

INIT_5 INIT_6

0 other other other other other other

1 prot other other other other other

2 other prot other other other other

3 prot prot other other other other

4 other other prot other other other

5 prot other prot other other other

...63 prot prot prot prot prot prot

prot = protection signal

other = non-protection signal

When the corresponding bit or bits in both the Control line setting and the INIT_Xline are TRUE:

• The CLOSE_CB output is blocked until the protection is reset• If the INIT_X line defined as the protection signal is activated during the

discrimination time, the AR function goes to lockout• If the INIT_X line defined as the protection signal stays active longer than the

time set by the Max trip time setting, the AR function goes to lockout (long trip)• The UNSUC_RECL output is activated after a pre-defined two minutes

(alarming earth-fault).

9.4.3.2 Zone coordination

Zone coordination is used in the zone sequence between local protection units anddownstream devices. At the falling edge of the INC_SHOTP line, the value of theshot pointer is increased by one, unless a shot is in progress or the shot pointeralready has the maximum value.

The falling edge of the INC_SHOTP line is not accepted if any of the shots are inprogress.



9.4.3.3 Master and slave scheme

With the cooperation between the AR units in the same IED or between IEDs,sequential reclosings of two breakers at a line end in a 1½-breaker, double breakeror ring-bus arrangement can be achieved. One unit is defined as a master and itexecutes the reclosing first. If the reclosing is successful and no trip takes place, thesecond unit, that is the slave, is released to complete the reclose shot. Withpersistent faults, the breaker reclosing is limited to the first breaker.

A070877 V1 EN

Figure 338: Master and slave scheme

If the AR unit is defined as a master by setting its terminal priority to high:

• The unit activates the CMD_WAIT output to the low priority slave unitwhenever a shot is in progress, a reclosing is unsuccessful or theBLK_RCLM_T input is active

• The CMD_WAIT output is reset one second after the reclose command is givenor if the sequence is unsuccessful when the reclaim time elapses.

If the AR unit is defined as a slave by setting its terminal priority to low:

• The unit waits until the master releases the BLK_RECL_T input (theCMD_WAIT output in the master). Only after this signal has been deactivated,the reclose time for the slave unit can be started.

• The slave unit is set to a lockout state if the BLK_RECL_T input is notreleased within the time defined by the Max wait time setting , which followsthe initiation of an auto-reclose shot.

If the terminal priority of the AR unit is set to "none", the AR unit skips all theseactions.

9.4.3.4 Thermal overload blocking

An alarm or start signal from the thermal overload protection (T1PTTR) can berouted to the input BLK_THERM to block and hold the reclose sequence. TheBLK_THERM signal does not affect the starting of the sequence. When the reclosetime has elapsed and the BLK_THERM input is active, the shot is not ready until theBLK_THERM input deactivates. Should the BLK_THERM input remain activelonger than the time set by the setting Max block time, the AR function goes to lockout.

If the BLK_THERM input is activated when the auto wait timer is running, the autowait timer is reset and the timer restarted when the BLK_THERM input deactivates.




The reclosing operation can be enabled and disabled with the Reclosing operationsetting. This setting does not disable the function, only the reclosing functionality.The setting has three parameter values: “On”, “External Ctl” and ”Off”. The settingvalue “On” enables the reclosing operation and “Off” disables it. When the settingvalue “External Ctl” is selected, the reclosing operation is controlled with theRECL_ON input .

The operation of the autoreclosing function can be described using a modulediagram. All the modules in the diagram are explained in the next sections.

A070864 V2 EN


9.4.4.1 Signal collection and delay logic

When the protection trips, the initiation of auto-reclose shots is in mostapplications executed with the INIT_1...6 inputs. The DEL_INIT2...4inputs are not used. In some countries, starting the protection stage is also used forthe shot initiation. This is the only time when the DEL_INIT inputs are used.



A070865 V2 EN

Figure 340: Schematic diagram of delayed initiation input signals

In total, the AR function contains six separate initiation lines used for the initiationor blocking of the auto-reclose shots. These lines are divided into two types ofchannels. In three of these channels, the signal to the AR function can be delayed,whereas the other three channels do not have any delaying capability.

Each channel that is capable of delaying a start signal has four time delays. Thetime delay is selected based on the shot pointer in the AR function. For the firstreclose attempt, the first time delay is selected; for the second attempt, the secondtime delay and so on. For the fourth and fifth attempts, the time delays are the same.

Time delay settings for the DEL_INIT_2 signal are as follows:

• Str 2 delay shot 1• Str 2 delay shot 2• Str 2 delay shot 3• Str 2 delay shot 4







Normally, only two or three reclose attempts are made. The third and fourth timesare used to provide the so called fast final trip to lockout.

OR CB_TRIP

CB_POSITIONCB_READY

CB_CLOSE

PHLPTOC

I_A

I_B START

OPERATE

I_C

BLOCK

ENA_MULT

DARRECOPEN _CB

CLOSE_CBCMD_WAIT

INPROLOCKED

PROT _CRDUNSUC_RECL

DEL_INIT_4DEL_INIT_3DEL_INIT_2INIT_6INIT_5INIT_4INIT_3INIT_2INIT_1

SYNC

INC_SHOTPCB_READYCB_POS

RECL_ONINHIBIT_RECL

BLK_RCLM_TBLK_RECL_T

BLK_THERM

AR_ONREADY

A070866 V3 EN

Figure 341: Autoreclose configuration example

Delayed DEL_INIT_2...4 signals are used only when the auto-reclose shot isinitiated with the start signal of a protection stage. After a start delay, the ARfunction opens the circuit breaker and an auto-reclose shot is initiated. When theshot is initiated with the trip signal of the protection, the protection function tripsthe circuit breaker and simultaneously initiates the auto-reclose shot.

If the circuit breaker is manually closed against the fault, that is, if SOTF is used,the fourth time delay can automatically be taken into use. This is controlled withthe internal logic of the AR function and the Fourth delay in SOTF parameter.

A typical auto-reclose situation is where one auto-reclose shot has been performedafter the fault was detected. There are two types of such cases: operation initiatedwith protection start signal and operation initiated with protection trip signal. Inboth cases, the auto-reclose sequence is successful: the reclaim time elapses and nonew sequence is started.



A070867 V1 EN

Figure 342: Signal scheme of autoreclose operation initiated with protectionstart signal

The auto-reclose shot is initiated with a start signal of the protection function afterthe start delay time has elapsed. The auto-reclose starts when the Str 2 delay shot 1setting elapses.

A070868 V1 EN

Figure 343: Signal scheme of autoreclose operation initiated with protectionoperate signal

The auto-reclose shot is initiated with a trip signal of the protection function. Theauto-reclose starts when the protection operate delay time elapses.

Normally, all trip and start signals are used to initiate an auto-reclose shot and tripthe circuit breaker. If any of the input signals INIT_X or DEL_INIT_X are usedfor blocking, the corresponding bit in the Tripping line setting must be FALSE.This is to ensure that the circuit breaker does not trip from that signal, that is, thesignal does not activate the OPEN_CB output. The default value for the setting is"63", which means that all initiation signals activate the OPEN_CB output. Thelowest bit in the Tripping line setting corresponds to the INIT_1 input, the highestbit to the INIT_6 line.



9.4.4.2 Shot initiation

A070869 V1 EN

Figure 344: Example of an auto-reclose program with a reclose scheme matrix

In the AR function, each shot can be programmed to locate anywhere in the reclosescheme matrix. The shots are like building blocks used to design the recloseprogram. The building blocks are called CBBs. All blocks are alike and havesettings which give the attempt number (columns in the matrix), the initiation orblocking signals (rows in the matrix) and the reclose time of the shot.

The settings related to CBB configuration are:

• First...Seventh reclose time• Init signals CBB1…CBB7• Blk signals CBB1…CBB7• Shot number CBB1…CBB7

The reclose time defines the open and dead times, that is, the time between theOPEN_CB and the CLOSE_CB commands. The Init signals CBBx setting definesthe initiation signals. The Blk signals CBBx setting defines the blocking signals thatare related to the CBB (rows in the matrix). The Shot number CBB1…CBB7 settingdefines which shot is related to the CBB (columns in the matrix). For example,CBB1 settings are:



• First reclose time = 1.0s• Init signals CBB1 = 7 (three lowest bits: 111000 = 7)• Blk signals CBB1 = 16 (the fifth bit: 000010 = 16)• Shot number CBB1 = 1

CBB2 settings are:

• Second reclose time = 10s• Init signals CBB2 = 6 (the second and third bits: 011000 = 6)• Blk signals CBB2 = 16 (the fifth bit: 000010 = 16)• Shot number CBB2 = 2

CBB3 settings are:

• Third reclose time = 30s• Init signals CBB3 = 4 (the third bit: 001000 = 4)• Blk signals CBB3 = 16 (the fifth bit: 000010 = 16)• Shot number CBB3 = 3

CBB4 settings are:

• Fourth reclose time = 0.5s• Init signals CBB4 = 8 (the fourth bit: 000100 = 8)• Blk signals CBB4 = 0 (no blocking signals related to this CBB)• Shot number CBB4 = 1

If a shot is initiated from the INIT_1 line, only one shot is allowed beforelockout. If a shot is initiated from the INIT_3 line, three shots are allowed beforelockout.

A sequence initiation from the INIT_4 line leads to a lockout after two shots. In asituation where the initiation is made from both the INIT_3 and INIT_4 lines, athird shot is allowed, that is, CBB3 is allowed to start. This is called conditionallockout. If the initiation is made from the INIT_2 and INIT_3 lines, animmediate lockout occurs.

The INIT_5 line is used for blocking purposes. If the INIT_5 line is activeduring a sequence start, the reclose attempt is blocked and the AR function goes tolockout.

If more than one CBBs are started with the shot pointer, the CBBwith the smallest individual number is always selected. Forexample, if the INIT_2 and INIT_4 lines are active for thesecond shot, that is, the shot pointer is 2, CBB2 is started instead ofCBB5.



Even if the initiation signals are not received from the protection functions, the ARfunction can be set to continue from the second to the fifth reclose shot. The ARfunction can, for example, be requested to automatically continue with thesequence when the circuit breaker fails to close when requested. In such a case, theAR function issues a CLOSE_CB command. When the wait close time elapses, thatis, the closing of the circuit breaker fails, the next shot is automatically started.Another example is the embedded generation on the power line, which can makethe synchronism check fail and prevent the reclosing. If the auto-reclose sequenceis continued to the second shot, a successful synchronous reclosing is more likelythan with the first shot, since the second shot lasts longer than the first one.

A070870 V1 EN

Figure 345: Logic diagram of auto-initiation sequence detection

Automatic initiation can be selected with the Auto initiation Cnd setting to be thefollowing:



• Not allowed: no automatic initiation is allowed• When the synchronization fails, the automatic initiation is carried out when the

auto wait time elapses and the reclosing is prevented due to a failure during thesynchronism check

• When the circuit breaker does not close, the automatic initiation is carried outif the circuit breaker does not close within the wait close time after issuing thereclose command

• Both: the automatic initiation is allowed when synchronization fails or thecircuit breaker does not close.

The Auto init parameter defines which INIT_X lines are activatedin the auto-initiation. The default value for this parameter is "0",which means that no auto-initiation is selected.

A070871 V1 EN

Figure 346: Example of an auto-initiation sequence with synchronization failurein the first shot and circuit breaker closing failure in the second shot

In the first shot, the synchronization condition is not fulfilled (SYNC is FALSE).When the auto wait timer elapses, the sequence continues to the second shot.During the second reclosing, the synchronization condition is fulfilled and the closecommand is given to the circuit breaker after the second reclose time has elapsed.

After the second shot, the circuit breaker fails to close when the wait close time haselapsed. The third shot is started and a new close command is given after the thirdreclose time has elapsed. The circuit breaker closes normally and the reclaim timestarts. When the reclaim time has elapsed, the sequence is concluded successful.

9.4.4.3 Shot pointer controller

The execution of a reclose sequence is controlled by a shot pointer. It can beadjusted with the SHOT_PTR monitored data.

The shot pointer starts from an initial value "1" and determines according to thesettings whether or not a certain shot is allowed to be initiated. After every shot,



the shot pointer value increases. This is carried out until a successful reclosing orlockout takes place after a complete shot sequence containing a total of five shots.

A070872 V1 EN

Figure 347: Shot pointer function

Every time the shot pointer increases, the reclaim time starts. When the reclaimtime ends, the shot pointer sets to its initial value, unless no new shot is initiated.The shot pointer increases when the reclose time elapses or at the falling edge ofthe INC_SHOTP signal.

When SHOT_PTR has the value six, the AR function is in a so called pre-lockoutstate. If a new initiation occurs during the pre-lockout state, the AR function goesto lockout. Therefore, a new sequence initiation during the pre-lockout state is notpossible.

The AR function goes to the pre-lockout state in the following cases:

• During SOTF• When the AR function is active, it stays in a pre-lockout state for the time

defined by the reclaim time• When all five shots have been executed• When the frequent operation counter limit is reached. A new sequence

initiation forces the AR function to lockout.

9.4.4.4 Reclose controller

The reclose controller calculates the reclose, discrimination and reclaim times. Thereclose time is started when the INPRO signal is activated, that is, when thesequence starts and the activated CBB defines the reclose time.

When the reclose time has elapsed, the CLOSE_CB output is not activated until thefollowing conditions are fulfilled:



• The SYNC input must be TRUE if the particular CBB requires informationabout the synchronism

• All AR initiation inputs that are defined protection lines (using the Controlline setting) are inactive

• The circuit breaker is open• The circuit breaker is ready for the close command, that is, the CB_READY

input is TRUE.

If at least one of the conditions is not fulfilled within the time set with the Autowait time parameter, the auto-reclose sequence is locked.

The synchronism requirement for the CBBs can be defined with theSynchronisation set setting, which is a bit mask. The lowest bit in theSynchronisation set setting is related to CBB1 and the highest bit to CBB7. Forexample, if the setting is set to "1", only CBB1 requires synchronism. If the settingis it set to "7", CBB1, CBB2 and CBB3 require the SYNC input to be TRUE beforethe reclosing command can be given.

A070873 V1 EN

Figure 348: Initiation during discrimination time - AR function goes to lockout

The discrimination time starts when the close command CLOSE_CB has beengiven. If a start input is activated before the discrimination time has elapsed, theAR function goes to lockout. The default value for each discrimination time iszero. The discrimination time can be adjusted with the Dsr time shot 1…4 parameter.



A070874 V1 EN

Figure 349: Initiation after elapsed discrimination time - new shot begins

9.4.4.5 Sequence controller

When the LOCKED output is active, the AR function is in lockout. This means thatnew sequences cannot be initialized, because AR is insensitive to initiationcommands. It can be released from the lockout state in the following ways:

• The function is reset through communication with the RsRec parameter• The lockout is automatically reset after the reclaim time, if the Auto lockout

reset setting is in use.

If the Auto lockout reset setting is not in use, the lockout can bereleased only with the RsRec parameter.

The AR function can go to lockout for many reasons:

• The INHIBIT_RECL input is active• All shots have been executed and a new initiation is made (final trip)• The time set with the Auto wait time parameter expires and the automatic

sequence initiation is not allowed because of a synchronization failure• The time set with the Wait close time parameter expires, that is, the circuit

breaker does not close or the automatic sequence initiation is not allowed dueto a closing failure of the circuit breaker

• A new shot is initiated during the discrimination time• The time set with the Max wait time parameter expires, that is, the master unit

does not release the slave unit



• The frequent operation counter limit is reached and new sequence is initiated.The lockout is released when the recovery timer elapses

• The protection trip signal has been active longer than the time set with the Maxwait time parameter since the shot initiation

• The circuit breaker is closed manually during an auto-reclose sequence and themanual close mode is FALSE.

9.4.4.6 Protection coordination controller

The PROT_CRD output is used for controlling the protection functions. In severalapplications, such as fuse-saving applications involving down-stream fuses,tripping and initiation of shot 1 should be fast (instantaneous or short-timedelayed). The tripping and initiation of shots 2, 3 and definite tripping time shouldbe delayed.

In this example, two overcurrent elements PHLPTOC and PHIPTOC are used.PHIPTOC is given an instantaneous characteristic and PHLPTOC is given a timedelay.

The PROT_CRD output is activated, if the SHOT_PTR value is the same or higherthan the value defined with the Protection crd limit setting and all initializationsignals have been reset. The PROT_CRD output is reset under the followingconditions:

• If the cut-out time elapses• If the reclaim time elapses and the AR function is ready for a new sequence• If the AR function is in lockout or disabled, that is, if the value of the

Protection crd mode setting is "AR inoperative" or "AR inop, CB man".

The PROT_CRD output can also be controlled with the Protection crd modesetting. The setting has the following modes:

• "no condition": the PROT_CRD output is controlled only with the Protectioncrd limit setting

• "AR inoperative": the PROT_CRD output is active, if the AR function isdisabled or in the lockout state, or if the INHIBIT_RECL input is active

• "CB close manual": the PROT_CRD output is active for the reclaim time if thecircuit breaker has been manually closed, that is, the AR function has notissued a close command

• "AR inop, CB man": both the modes "AR inoperative" and "CB close manual"are effective

• "always": the PROT_CRD output is constantly active



Shot 1(CBB1)

0.3s

Shot 2(CBB2)15.0s

INIT_1 (I>>)

INIT_2 (I>)

INIT_3 (Io>)

Lockout

Lockout

Lockout

A070875 V3 EN

Figure 350: Configuration example of using the PROT_CRD output for protectionblocking

If the Protection crd limit setting has the value "1", the instantaneous three-phaseovercurrent protection function PHIPTOC is disabled or blocked after the first shot.

9.4.4.7 Circuit breaker controller

Circuit breaker controller contains two features: SOTF and frequent-operationcounter. SOTF protects the AR function in permanent faults.

The circuit breaker position information is controlled with the CB closed Pos statussetting. The setting value "TRUE” means that when the circuit breaker is closed,the CB_POS input is TRUE. When the setting value is “FALSE”, the CB_POSinput is FALSE, provided that the circuit breaker is closed. The reclose commandpulse time can be controlled with the Close pulse time setting: the CLOSE_CBoutput is active for the time set with the Close pulse time setting. The CLOSE_CBoutput is deactivated also when the circuit breaker is detected to be closed, that is,when the CB_POS input changes from open state to closed state. The Wait closetime setting defines the time after the CLOSE_CB command activation, duringwhich the circuit breaker should be closed. If the closing of circuit breaker does nothappen during this time, the auto-reclose function is driven to lockout or, ifallowed, an auto-initiation is activated.

The main motivation for auto-reclosing to begin with is the assumption that thefault is temporary by nature, and that a momentary de-energizing of the power lineand an automatic reclosing restores the power supply. However, when the powerline is manually energized and an immediate protection trip is detected, it is verylikely that the fault is of a permanent type. A permanent fault is, for example,energizing a power line into a forgotten earthing after a maintenance work alongthe power line. In such cases, SOTF is activated, but only for the reclaim time afterenergizing the power line and only when the circuit breaker is closed manually andnot by the AR function.

SOTF disables any initiation of an auto-reclose shot. The energizing of the powerline is detected from the CB_POS information.

SOTF is activated when the AR function is enabled or when the AR function isstarted and the SOTF should remain active for the reclaim time.

When SOTF is detected, the parameter SOTF is active.



If the Manual close mode setting is set to FALSE and the circuitbreaker has been manually closed during an auto-reclose shot, theAR unit goes to an immediate lockout.

If the Manual close mode setting is set to TRUE and the circuitbreaker has been manually closed during an auto-reclose shot (theINPRO is active), the shot is considered as completed.

When SOTF starts, reclaim time is restarted, provided that it isrunning.

The frequent-operation counter is intended for blocking the auto-reclose function incases where the fault causes repetitive auto-reclose sequences during a short periodof time. For instance, if a tree causes a short circuit and, as a result, there are auto-reclose shots within a few minutes interval during a stormy night. These types offaults can easily damage the circuit breaker if the AR function is not locked by afrequent-operation counter.

The frequent-operation counter has three settings:

• Frq Op counter limit• Frq Op counter time• Frq Op recovery time

The Frq Op counter limit setting defines the number of reclose attempts that areallowed during the time defined with the Frq Op counter time setting. If the setvalue is reached within a pre-defined period defined with the Frq Op counter timesetting, the AR function goes to lockout when a new shot begins, provided that thecounter is still above the set limit. The lockout is released after the recovery timehas elapsed. The recovery time can be defined with the Frq Op recovery time setting .

If the circuit breaker is manually closed during the recovery time, the reclaim timeis activated after the recovery timer has elapsed.

9.4.5 CountersThe AR function contains six counters. Their values are stored in a semi-retainmemory. The counters are increased at the rising edge of the reclose command.The counters count the following situations:

• COUNTER: counts every reclose command activation• CNT_SHOT1: counts reclose commands that are executed from shot 1• CNT_SHOT2: counts reclose commands that are executed from shot 2



• CNT_SHOT3: counts reclose commands that are executed from shot 3• CNT_SHOT4: counts reclose commands that are executed from shot 4• CNT_SHOT5: counts reclose commands that are executed from shot 5

The counters are disabled through communication with the DsaCnt parameter.When the counters are disabled, the values are not updated.

The counters are reset through communication with the RsCnt parameter.

9.4.6 ApplicationModern electric power systems can deliver energy to users very reliably. However,different kind of faults can occur. Protection relays play an important role indetecting failures or abnormalities in the system. They detect faults and givecommands for corresponding circuit breakers to isolate the defective elementbefore excessive damage or a possible power system collapse occurs. A fastisolation also limits the disturbances caused for the healthy parts of the power system.

The faults can be transient, semi-transient or permanent. Permanent fault, forexample in power cables, means that there is a physical damage in the faultlocation that must first be located and repaired before the network voltage can berestored.

In overhead lines, the insulating material between phase conductors is air. Themajority of the faults are flash-over arcing faults caused by lightning, for example.Only a short interruption is needed for extinguishing the arc. These faults aretransient by nature.

A semi-transient fault can be caused for example by a bird or a tree branch fallingon the overhead line. The fault disappears on its own if the fault current burns thebranch or the wind blows it away.

Transient and semi-transient faults can be cleared by momentarily de-energizingthe power line. Using the auto-reclose function minimizes interruptions in thepower system service and brings the power back on-line quickly and effortlessly.

The basic idea of the auto-reclose function is simple. In overhead lines, where thepossibility of self-clearing faults is high, the auto-reclose function tries to restorethe power by reclosing the breaker. This is a method to get the power system backinto normal operation by removing the transient or semi-transient faults. Severaltrials, that is, auto-reclose shots are allowed. If none of the trials is successful andthe fault persists, definite final tripping follows.

The auto-reclose function can be used with every circuit breaker that has the abilityfor a reclosing sequence. In DARREC auto-reclose function the implementingmethod of auto-reclose sequences is patented by ABB



Table 569: Important definitions related to auto-reclosing

auto-reclose shot an operation where after a preset time the breaker is closed from the breakertripping caused by protection

auto-reclosesequence

a predefined method to do reclose attempts (shots) to restore the power system

SOTF If the protection detects a fault immediately after an open circuit breaker hasbeen closed, it indicates that the fault was already there. It can be, for example,a forgotten earthing after maintenance work. Such closing of the circuit breakeris known as switch on to fault. Autoreclosing in such conditions is prohibited.

final trip Occurs in case of a permanent fault, when the circuit breaker is opened for thelast time after all programmed auto-reclose operations. Since no auto-reclosingfollows, the circuit breaker remains open. This is called final trip or definite trip.

9.4.6.1 Shot initiation

A070869 V1 EN

Figure 351: Example of an auto-reclose program with a reclose scheme matrix

In the AR function, each shot can be programmed to locate anywhere in the reclosescheme matrix. The shots are like building blocks used to design the recloseprogram. The building blocks are called CBBs. All blocks are alike and havesettings which give the attempt number (columns in the matrix), the initiation orblocking signals (rows in the matrix) and the reclose time of the shot.



The settings related to CBB configuration are:

• First...Seventh reclose time• Init signals CBB1…CBB7• Blk signals CBB1…CBB7• Shot number CBB1…CBB7

The reclose time defines the open and dead times, that is, the time between theOPEN_CB and the CLOSE_CB commands. The Init signals CBBx setting definesthe initiation signals. The Blk signals CBBx setting defines the blocking signals thatare related to the CBB (rows in the matrix). The Shot number CBB1…CBB7 settingdefines which shot is related to the CBB (columns in the matrix). For example,CBB1 settings are:

• First reclose time = 1.0s• Init signals CBB1 = 7 (three lowest bits: 111000 = 7)• Blk signals CBB1 = 16 (the fifth bit: 000010 = 16)• Shot number CBB1 = 1

CBB2 settings are:

• Second reclose time = 10s• Init signals CBB2 = 6 (the second and third bits: 011000 = 6)• Blk signals CBB2 = 16 (the fifth bit: 000010 = 16)• Shot number CBB2 = 2

CBB3 settings are:

• Third reclose time = 30s• Init signals CBB3 = 4 (the third bit: 001000 = 4)• Blk signals CBB3 = 16 (the fifth bit: 000010 = 16)• Shot number CBB3 = 3

CBB4 settings are:

• Fourth reclose time = 0.5s• Init signals CBB4 = 8 (the fourth bit: 000100 = 8)• Blk signals CBB4 = 0 (no blocking signals related to this CBB)• Shot number CBB4 = 1

If a shot is initiated from the INIT_1 line, only one shot is allowed beforelockout. If a shot is initiated from the INIT_3 line, three shots are allowed beforelockout.

A sequence initiation from the INIT_4 line leads to a lockout after two shots. In asituation where the initiation is made from both the INIT_3 and INIT_4 lines, athird shot is allowed, that is, CBB3 is allowed to start. This is called conditional



lockout. If the initiation is made from the INIT_2 and INIT_3 lines, animmediate lockout occurs.

The INIT_5 line is used for blocking purposes. If the INIT_5 line is activeduring a sequence start, the reclose attempt is blocked and the AR function goes tolockout.

If more than one CBBs are started with the shot pointer, the CBBwith the smallest individual number is always selected. Forexample, if the INIT_2 and INIT_4 lines are active for thesecond shot, that is, the shot pointer is 2, CBB2 is started instead ofCBB5.

Even if the initiation signals are not received from the protection functions, the ARfunction can be set to continue from the second to the fifth reclose shot. The ARfunction can, for example, be requested to automatically continue with thesequence when the circuit breaker fails to close when requested. In such a case, theAR function issues a CLOSE_CB command. When the wait close time elapses, thatis, the closing of the circuit breaker fails, the next shot is automatically started.Another example is the embedded generation on the power line, which can makethe synchronism check fail and prevent the reclosing. If the auto-reclose sequenceis continued to the second shot, a successful synchronous reclosing is more likelythan with the first shot, since the second shot lasts longer than the first one.



A070870 V1 EN

Figure 352: Logic diagram of auto-initiation sequence detection

Automatic initiation can be selected with the Auto initiation Cnd setting to be thefollowing:

• Not allowed: no automatic initiation is allowed• When the synchronization fails, the automatic initiation is carried out when the

auto wait time elapses and the reclosing is prevented due to a failure during thesynchronism check

• When the circuit breaker does not close, the automatic initiation is carried outif the circuit breaker does not close within the wait close time after issuing thereclose command

• Both: the automatic initiation is allowed when synchronization fails or thecircuit breaker does not close.



The Auto init parameter defines which INIT_X lines are activatedin the auto-initiation. The default value for this parameter is "0",which means that no auto-initiation is selected.

A070871 V1 EN

Figure 353: Example of an auto-initiation sequence with synchronization failurein the first shot and circuit breaker closing failure in the second shot

In the first shot, the synchronization condition is not fulfilled (SYNC is FALSE).When the auto wait timer elapses, the sequence continues to the second shot.During the second reclosing, the synchronization condition is fulfilled and the closecommand is given to the circuit breaker after the second reclose time has elapsed.

After the second shot, the circuit breaker fails to close when the wait close time haselapsed. The third shot is started and a new close command is given after the thirdreclose time has elapsed. The circuit breaker closes normally and the reclaim timestarts. When the reclaim time has elapsed, the sequence is concluded successful.

9.4.6.2 Sequence

The auto reclose sequence is implemented by using CBBs. The highest possibleamount of CBBs is seven. If the user wants to have, for example, a sequence ofthree shots, only the first three CBBs are needed. Using building blocks instead offixed shots gives enhanced flexibility, allowing multiple and adaptive sequences.

Each CBB is identical. The Shot number CBB_ setting defines at which point in theauto-reclose sequence the CBB should be performed, that is, whether the particularCBB is going to be the first, second, third, fourth or fifth shot.

During the initiation of a CBB, the conditions of initiation and blocking arechecked. This is done for all CBBs simultaneously. Each CBB that fulfils theinitiation conditions requests an execution.

The function also keeps track of shots already performed, that is, at which point theauto-reclose sequence is from shot 1 to lockout. For example, if shots 1 and 2 havealready been performed, only shots 3 to 5 are allowed.

Additionally, the Enable shot jump setting gives two possibilities:



• Only such CBBs that are set for the next shot in the sequence can be acceptedfor execution. For example, if the next shot in the sequence should be shot 2, arequest from CBB set for shot 3 is rejected.

• Any CBB that is set for the next shot or any of the following shots can beaccepted for execution. For example, if the next shot in the sequence should beshot 2, also CBBs that are set for shots 3, 4 and 5 are accepted. In other words,shot 2 can be ignored.

In case there are multiple CBBs allowed for execution, the CBB with the smallestnumber is chosen. For example, if CBB2 and CBB4 request an execution, CBB2 isallowed to execute the shot.

The auto-reclose function can perform up to five auto-reclose shots or cycles.

9.4.6.3 Configuration examples

OR CB_TRIP

Circuit breaker position information from binary inputConditions to verify if circuit breaker is ready to be reclosed

CB_CLOSE

PHLPTOC

I_A

I_B START

OPERATE

I_C

BLOCK

ENA_MULT

PHHPTOC

I_A

I_B START

OPERATE

I_C

BLOCK

ENA_MULT

EFLPTOC

Io

BLOCK START

OPERATE

ENA_MULT

DARRECOPEN _CB

CLOSE _CBCMD_WAIT

INPROLOCKED

PROT_CRDUNSUC_RECL

DEL_INIT _4DEL_INIT _3DEL_INIT _2INIT _6INIT _5INIT _4INIT _3INIT _2INIT _1

SYNC

INC_SHOTPCB_READYCB_POS

RECL_ONINHIBIT _RECL

BLK _RCLM_TBLK _RECL_T

BLK _THERM

AR_ONREADY

A070886 V4 EN

Figure 354: Example connection between protection and autoreclose functionsin IED configuration

It is possible to create several sequences for a configuration.

Autoreclose sequences for overcurrent and non-directional earth-fault protectionapplications where high speed and delayed autoreclosings are needed can be asfollows:



Example 1.The sequence is implemented by two shots which have the same reclosing time forall protection functions, namely I>>, I> and Io>. The initiation of the shots is doneby activating the operating signals of the protection functions.

A070887 V1 EN

Figure 355: Autoreclose sequence with two shots

tHSAR Time delay of high-speed autoreclosing, here: First reclose time

tDAR Time delay of delayed autoreclosing, here: Second reclose time

tProtection Operating time for the protection stage to clear the fault

tCB_O Operating time for opening the circuit breaker

tCB_C Operating time for closing the circuit breaker

In this case, the sequence needs two CBBs. The reclosing times for shot 1 and shot2 are different, but each protection function initiates the same sequence. The CBBsequence is as follows:

Shot 1(CBB1)

0.3s

Shot 2(CBB2)15.0s

INIT_1 (I>>)

INIT_2 (I>)

INIT_3 (Io>)

Lockout

Lockout

Lockout

A071270 V2 EN

Figure 356: Two shots with three initiation lines



Table 570: Settings for configuration example 1

Setting name Setting valueShot number CBB1 1

Init signals CBB1 7 (lines 1,2 and 3 = 1+2+4 = 7)

First reclose time 0.3s (an example)

Shot number CBB2 2

Init signals CBB2 7 (lines 1,2 and 3 = 1+2+4 = 7)

Second reclose time 15.0s (an example)

Example 2There are two separate sequences implemented with three shots. Shot 1 isimplemented by CBB1 and it is initiated with the high stage of the overcurrentprotection (I>>). Shot 1 is set as a high-speed autoreclosing with a short timedelay. Shot 2 is implemented with CBB2 and meant to be the first shot of theautoreclose sequence initiated by the low stage of the overcurrent protection (I>)and the low stage of the non-directional earth-fault protection (Io>). It has the samereclosing time in both situations. It is set as a high-speed autoreclosing forcorresponding faults. The third shot, which is the second shot in the autoreclosesequence initiated by I> or Io>, is set as a delayed autoreclosing and executed afteran unsuccessful high-speed autoreclosing of a corresponding sequence.

A071272 V1 EN

Figure 357: Autoreclose sequence with two shots with different shot settingsaccording to initiation signal



tHSAR Time delay of high-speed autoreclosing, here: First reclose time

tDAR Time delay of delayed autoreclosing, here: Second reclose time

tl>> Operating time for the I>> protection stage to clear the fault

tl> or lo> Operating time for the I> or Io> protection stage to clear the fault

tCB_O Operating time for opening the circuit breaker

tCB_C Operating time for closing the circuit breaker

In this case, the number of needed CBBs is three, that is, the first shot's reclosingtime depends on the initiation signal. The CBB sequence is as follows:

INIT_1 (I>>)

INIT_2 (I>)

INIT_3 (Io>)

Shot 1(CBB1)

1.0s

Shot 1(CBB2)

0.2s

Shot 2(CBB3)10.0s

Lockout

Lockout

Lockout

A071274 V2 EN

Figure 358: Three shots with three initiation lines

If the sequence is initiated from the INIT_1 line, that is, the overcurrentprotection high stage, the sequence is one shot long. On the other hand, if thesequence is initiated from the INIT_2 or INIT_3 lines, the sequence is two shotslong.

Table 571: Settings for configuration example 2

Setting name Setting valueShot number CBB1 1

Init signals CBB1 1 (line 1)

First reclose time 0.0s (an example)

Shot number CBB2 1

Init signals CBB2 6 (lines 2 and 3 = 2+4 = 6)

Second reclose time 0.2s (an example)

Shot number CBB3 2

Init signals CBB3 6 (lines 2 and 3 = 2+4 = 6)

Third reclose time 10.0s

9.4.6.4 Delayed initiation lines

The auto-reclose function consists of six individual auto-reclose initiation linesINIT_1...INIT 6 and three delayed initiation lines:



• DEL_INIT_2• DEL_INIT_3• DEL_INIT_4

DEL_INIT_2 and INIT_2 are connected together with an OR-gate, as are inputs3 and 4. Inputs 1, 5 and 6 do not have any delayed input. From the auto-reclosingpoint of view, it does not matter whether INIT_x or DEL_INIT_x line is usedfor shot initiation or blocking.

The auto-reclose function can also open the circuit breaker from any of theinitiation lines. It is selected with the Tripping line setting. As a default, allinitiation lines activate the OPEN_CB output.

A070276 V1 EN

Figure 359: Simplified logic diagram of initiation lines

Each delayed initiation line has four different time settings:

Table 572: Settings for delayed initiation lines

Setting name Description and purposeStr x delay shot 1 Time delay for the DEL_INIT_x line, where x is

the number of the line 2, 3 or 4. Used for shot 1.

Str x delay shot 2 Time delay for the DEL_INIT_x line, used forshot 2.

Str x delay shot 3 Time delay for the DEL_INIT_x line, used forshot 3.

Str x delay shot 4 Time delay for the DEL_INIT_x line, used forshots 4 and 5. Optionally, can also be used withSOTF.



9.4.6.5 Shot initiation from protection start signal

In it simplest, all auto-reclose shots are initiated by protection trips. As a result, alltrip times in the sequence are the same. This is why using protection trips may notbe the optimal solution. Using protection start signals instead of protection trips forinitiating shots shortens the trip times.

Example 1When a two-shot-sequence is used, the start information from the protectionfunction is routed to the DEL_INIT 2 input and the operate information to theINIT_2 input. The following conditions have to apply:

• protection operate time = 0.5s• Str 2 delay shot 1 = 0.05s• Str 2 delay shot 2 = 60s• Str 2 delay shot 3 = 60s

Operation in a permanent fault:

1. Protection starts and activates the DEL_INIT 2 input.2. After 0.05 seconds, the first autoreclose shot is initiated. The function opens

the circuit breaker: the OPEN_CB output activates. The total trip time is theprotection start delay + 0.05 seconds + the time it takes to open the circuit breaker.

3. After the first shot, the circuit breaker is reclosed and the protection starts again.4. Because the delay of the second shot is 60 seconds, the protection is faster and

trips after the set operation time, activating the INIT 2 input. The secondshot is initiated.

5. After the second shot, the circuit breaker is reclosed and the protection startsagain.

6. Because the delay of the second shot is 60 seconds, the protection is faster andtrips after the set operation time. No further shots are programmed after thefinal trip. The function is in lockout and the sequence is considered unsuccessful.

Example 2The delays can be used also for fast final trip. The conditions are the same as inExample 1, with the exception of Str 2 delay shot 3 = 0.10 seconds.

The operation in a permanent fault is the same as in Example 1, except that afterthe second shot when the protection starts again, Str 2 delay shot 3 elapses beforethe protection operate time and the final trip follows. The total trip time is theprotection start delay + 0.10 seconds + the time it takes to open the circuit breaker.

9.4.6.6 Fast trip in Switch on to fault

The Str _ delay shot 4 parameter delays can also be used to achieve a fast andaccelerated trip with SOTF. This is done by setting the Fourth delay in SOTF



parameter to "1" and connecting the protection start information to thecorresponding DEL_INIT_ input.

When the function detects a closing of the circuit breaker, that is, any other closingexcept the reclosing done by the function itself, it always prohibits shot initiationfor the time set with the Reclaim time parameter. Furthermore, if the Fourth delayin SOTF parameter is "1", the Str _ delay shot 4 parameter delays are also activated.

Example 1The protection operation time is 0.5 seconds, the Fourth delay in SOTF parameteris set to "1" and the Str 2 delay shot 4 parameter is 0.05 seconds. The protectionstart signal is connected to the DEL_INIT_2 input.

If the protection starts after the circuit breaker closes, the fast trip follows after theset 0.05 seconds. The total trip time is the protection start delay + 0.05 seconds +the time it takes to open the circuit breaker.

9.4.7 SignalsTable 573: DARREC Input signals

Name Type Default DescriptionINIT_1 BOOLEAN 0=False AR initialization / blocking signal 1

INIT_2 BOOLEAN 0=False AR initialization / blocking signal 2





DEL_INIT_2 BOOLEAN 0=False Delayed AR initialization / blocking signal 2



BLK_RECL_T BOOLEAN 0=False Blocks and resets reclose time

BLK_RCLM_T BOOLEAN 0=False Blocks and resets reclaim time

BLK_THERM BOOLEAN 0=False Blocks and holds the reclose shot from thethermal overload

CB_POS BOOLEAN 0=False Circuit breaker position input

CB_READY BOOLEAN 1=True Circuit breaker status signal

INC_SHOTP BOOLEAN 0=False A zone sequence coordination signal

INHIBIT_RECL BOOLEAN 0=False Interrupts and inhibits reclosing sequence

RECL_ON BOOLEAN 0=False Level sensitive signal for allowing (high) / notallowing (low) reclosing

SYNC BOOLEAN 0=False Synchronizing check fulfilled



Table 574: DARREC Output signals

Name Type DescriptionOPEN_CB BOOLEAN Open command for circuit breaker

CLOSE_CB BOOLEAN Close (reclose) command for circuit breaker

CMD_WAIT BOOLEAN Wait for master command

INPRO BOOLEAN Reclosing shot in progress, activated during deadtime

LOCKED BOOLEAN Signal indicating that AR is locked out

PROT_CRD BOOLEAN A signal for coordination between the AR and theprotection

UNSUC_RECL BOOLEAN Indicates an unsuccessful reclosing sequence

AR_ON BOOLEAN Autoreclosing allowed

READY BOOLEAN Indicates that the AR is ready for a new sequence

9.4.8 SettingsTable 575: DARREC Non group settings


5=off 1=on Operation Off/On

Reclosing operation 1=Off2=External Ctl3=On

1=Off Reclosing operation (Off, External Ctl /On)

Manual close mode 0=False1=True

0=False Manual close mode

Wait close time 50...10000 ms 50 250 Allowed CB closing time after reclosecommand

Max wait time 100...1800000 ms 100 10000 Maximum wait time for haltDeadTimerelease

Max trip time 100...10000 ms 100 10000 Maximum wait time for deactivation ofprotection signals

Close pulse time 10...10000 ms 10 200 CB close pulse time

Max Thm block time 100...1800000 ms 100 10000 Maximum wait time for thermal blockingsignal deactivation

Cut-out time 0...1800000 ms 100 10000 Cutout time for protection coordination

Reclaim time 100...1800000 ms 100 10000 Reclaim time

Dsr time shot 1 0...10000 ms 100 0 Discrimination time for first reclosing

Dsr time shot 2 0...10000 ms 100 0 Discrimination time for second reclosing

Dsr time shot 3 0...10000 ms 100 0 Discrimination time for third reclosing

Dsr time shot 4 0...10000 ms 100 0 Discrimination time for fourth reclosing

Terminal priority 1=None2=Low (follower)3=High (master)

1=None Terminal priority

Synchronisation set 0...127 0 Selection for synchronizing requirementfor reclosing




Parameter Values (Range) Unit Step Default DescriptionAuto wait time 0...60000 ms 10 2000 Wait time for reclosing condition fullfilling

Auto lockout reset 0=False1=True

1=True Automatic lockout reset

Protection crd limit 1...5 1 Protection coordination shot limit

Protection crd mode 1=No condition2=AR inoperative3=CB close manual4=AR inop, CB man5=Always

4=AR inop, CBman

Protection coordination mode

Auto initiation cnd 1=Not allowed2=When sync fails3=CBdoesn't close4=Both

2=When sync fails Auto initiation condition

Tripping line 0...63 0 Tripping line, defines INIT inputs whichcause OPEN_CB activation

Control line 0...63 63 Control line, defines INIT inputs whichare protection signals

Enable shot jump 0=False1=True

1=True Enable shot jumping

CB closed Pos status 0=False1=True

0=False Circuit breaker closed position status

Fourth delay in SOTF 0=False1=True

0=False Sets 4th delay into use for all DEL_INITsignals during SOTF

First reclose time 0...300000 ms 10 5000 Dead time for CBB1

Second reclose time 0...300000 ms 10 5000 Dead time for CBB2

Third reclose time 0...300000 ms 10 5000 Dead time for CBB3

Fourth reclose time 0...300000 ms 10 5000 Dead time for CBB4

Fifth reclose time 0...300000 ms 10 5000 Dead time for CBB5

Sixth reclose time 0...300000 ms 10 5000 Dead time for CBB6

Seventh reclose time 0...300000 ms 10 5000 Dead time for CBB7

Init signals CBB1 0...63 0 Initiation lines for CBB1







Blk signals CBB1 0...63 0 Blocking lines for CBB1










Parameter Values (Range) Unit Step Default DescriptionShot number CBB1 0...5 0 Shot number for CBB1

Shot number CBB2 0...5 0 Shot number for CBB2






Str 2 delay shot 1 0...300000 ms 10 0 Delay time for start2, 1st reclose

Str 2 delay shot 2 0...300000 ms 10 0 Delay time for start2 2nd reclose

Str 2 delay shot 3 0...300000 ms 10 0 Delay time for start2 3rd reclose

Str 2 delay shot 4 0...300000 ms 10 0 Delay time for start2, 4th reclose









Frq Op counter limit 0...250 0 Frequent operation counter lockout limit

Frq Op counter time 1...250 min 1 Frequent operation counter time

Frq Op recovery time 1...250 min 1 Frequent operation counter recovery time

Auto init 0...63 0 Defines INIT lines that are activated atauto initiation

9.4.9 Monitored dataTable 576: DARREC Monitored data

Name Type Values (Range) Unit DescriptionDISA_COUNT BOOLEAN 0=False

1=True Signal for counter

disabling

FRQ_OPR_CNT INT32 0...2147483647 Frequent operationcounter

FRQ_OPR_AL BOOLEAN 0=False1=True

Frequent operationcounter alarm

STATUS Enum -2=Unsuccessful-1=Not defined1=Ready2=In progress3=Successful

AR status signal forIEC61850

ACTIVE BOOLEAN 0=False1=True

Reclosing sequence is inprogress




Name Type Values (Range) Unit DescriptionINPRO_1 BOOLEAN 0=False

1=True Reclosing shot in

progress, shot 1

INPRO_2 BOOLEAN 0=False1=True

Reclosing shot inprogress, shot 2







DISCR_INPRO BOOLEAN 0=False1=True

Signal indicating thatdiscrimination time is inprogress

CUTOUT_INPRO BOOLEAN 0=False1=True

Signal indicating that cut-out time is in progress

SUC_RECL BOOLEAN 0=False1=True

Indicates a successfulreclosing sequence

UNSUC_CB BOOLEAN 0=False1=True

Indicates anunsuccessful CB closing

CNT_SHOT1 INT32 0...2147483647 Resetable operationcounter, shot 1





COUNTER INT32 0...2147483647 Resetable operationcounter, all shots

SHOT_PTR INT32 0...7 Shot pointer value

MAN_CB_CL BOOLEAN 0=False1=True

Indicates CB manualclosing during reclosingsequence

SOTF BOOLEAN 0=False1=True

Switch-onto-fault

DARREC Enum 1=on2=blocked3=test4=test/blocked5=off

Status

9.4.10 Technical dataTable 577: DARREC Technical data




9.4.11 Technical revision historyTable 578: Technical revision history

Technical revision ChangeB The PROT_DISA output removed and removed

the related settings

C The default value of the CB closed Pos statussetting changed from "True" to "False"

9.5 Tap changer control with voltage regulator OLATCC




Tap changer control with voltageregulator

OLATCC COLTC 90V


GUID-D28AEF4D-C38D-4F4A-908F-22FBFAB139CB V2 EN


9.5.3 FunctionalityThe tap changer control with voltage regulator function OLATCC (on-load tapchanger controller) is designed for regulating the voltage of power transformerswith on-load tap changers in distribution substations. OLATCC provides a manualor automatic voltage control of the power transformer by using the raising orlowering signals to the on-load tap changer.



The automatic voltage regulation can be used in single or parallel transformerapplications. Parallel operation can be based on Master/Follower (M/F), NegativeReactance Principle (NRP) or Minimizing Circulating Current (MCC).

OLATCC includes the line drop compensation (LDC) functionality, and the loaddecrease is possible with a dynamic voltage reduction.

Either definite time characteristic (DT) or inverse time characteristic (IDMT) isselectable for delays between the raising and lowering operations.

The function contains a blocking functionality. It is possible to block the voltagecontrol operations with an external signal or with the supervision functionality ofthe function.


The operation of the tap changer control with voltage regulator function can bedescribed using a module diagram. All the modules in the diagram are explained inthe next sections.



TCO

RSV

TAPCHG_FLLW

TAP_POS

I_CU_AB

I_BI_A

TR1_TAP_POSTR2_TAP_POSTR3_TAP_POS

LTC_BLOCK

RAISE_LOCALLOWER_LOCALCON_STATUS

PARALLEL

AUTO

TR2_I_ANGLTR3_I_AMPLTR3_I_ANGL

TR1_I_AMPLTR1_I_ANGLTR2_I_AMPL

Blockingscheme

ALARM

Auto parallel(NRP)

t

Timer

t

TR0_I_AMPLTR0_I_ANGL

Alarmindication

Auto parallel

(Follower)

Auto parallel(Master)

Auto parallel(MCC)

Auto single

Automatic voltage

regulation

Manualvoltage

regulation

FLLW1_CTLFLLW2_CTLFLLW3_CTLPAR_FAIL

Pulsecontrol

RAISE_OWNLOWER_OWN

Operationmode

selection

PARALLEL

AUTO

BLKD_I_LODBLKD_U_UNBLKD_U_OVBLKD_I_CIRBLKD_LTCBLK

TIMER_ON

GUID-BC07A9CF-D378-4A60-AFAF-DB6021BD082D V2 EN


9.5.5 Voltage and current measurementsThe measured voltage must be a phase-to-phase voltage from the regulated side.Typically, it is the phase-to-phase voltage U_AB from the secondary side of thepower transformer. If the phase voltages are measured, the voltage U_AB iscalculated internally in the IED.

Currents from the secondary side of the power transformer (I_A – I_C) haveseveral uses.



• The highest phase current value is used for overcurrent blocking.• The currents from the secondary side of the power transformer are used for

line drop compensation (average of the connected inputs).• The currents from the secondary side of the power transformer are used for

calculating the circulating current in the Negative Reactance Principle (NRP)and Minimizing Circulating Current (MCC) operation modes.

Both voltage U_AB and the phase currents from the secondary side (I_x, where xis A, B or C) are always measured using the value of the filtered fundamentalfrequency component (DFT). Hence, the harmonics are always suppressed.Moreover, the measured voltage value is continuously average-filtered with the eight-value-long sliding window where the resulting filtering delay is not compensated.The phase-compensated voltage U_A is always used in calculations, although it isnot connected. Um is the averaged value used for control and its magnitude can beread from the monitored data U_MEAS.

Similarly, the magnitude of the phase current of the own transformer, I_x, and thephase angle difference between the internally phase-compensated voltage U_A andphase current I_x are also average-filtered by the same length-fixed window. Thephase angle value can be read from the monitored data ANGL_UA_IA. Thesecurrents and phase angle differences are used solely on circulating currentcalculations.

The angle difference is used in Equation 79, Equation 80 andEquation 82.

There are minimum limits for the voltage and current magnitudes, resulting in themagnitude and phase angle difference values diverging from zero. The voltagemagnitude must exceed three percent of Un and the current I_A must exceed twopercent of In.

9.5.6 Tap changer position inputsThe position value of the tap changer can be brought to OLATCC as a resistancevalue, a mA signal or as a binary-coded signal. More information on how theresistance value, the mA signal or a binary-coded interface are implemented can befound in TPOSSLTC in the technical manual of the IED.

The indicated tap changer position of the own transformer is internally connectedto the TAP_POS input, and the tap changer positions of the parallel transformersare fed to the other TRx_TAP_POS inputs. This also defines the connectionidentity so that follower 1 is connected to TR1_TAP_POS, follower 2 is connectedto TR2_TAP_POS and follower 3 is connected to TR3_TAP_POS. The owntransformer position can be read from the monitored data TAP_POS. The followertap changer positions can also be read from the input data TRx_TAP_POS, wherex is a value between 1 and 3.



The tap changer position value is given in parentheses. For example, (0) indicatesthat there is no tap changer position connected or the tap changer position valuequality is bad. Typically, if no tap changer position is connected, all theTPOSSLTC binary inputs are FALSE by default and the value shown is (0). Avalue other than zero indicates bad quality. A bad-quality tap changer position isdealt by OLATCC like unconnected tap position information.

9.5.7 Operation mode selectionOLATCC has the Operation mode and Auto parallel mode settings for selecting thedesired operation mode. The Operation mode setting can have any of the followingvalues: "Manual", "Auto single", "Auto parallel" and "Input control". If theOperation mode setting is set to "Input control", the acting operation mode isdetermined by the inputs PARALLEL and AUTO. The PARALLEL input defines ifthe transformer (voltage regulator) is in the parallel or single mode. The AUTOinput defines the operation status in the single mode. The output signalsPARALLEL and AUTO echo fed input signals when the Operation mode setting isset to "Input control". Otherwise the PARALLEL and AUTO monitored datarepresent acting "Parallel or single operation" and "Auto/Manual indication"respectively.

Table 579: Acting operation mode determined by the operation mode inputs

PARALLEL AUTO Operation Mode0 0 Manual

0 1 Auto single

1 0 or 1 Auto parallel

Furthermore, if Operation mode has been set to "Auto parallel", the second settingparameter Auto parallel mode defines the parallel mode and the alternatives are"Auto master", "Auto follower", "MCC" or "NRP".

The acting operation mode can be read from the monitored data OPR_MODE_STS.

Command ExclusionAn acting operation mode change using two inputs (PARALLEL and AUTO) andsetting group change (either with the input or via menu) is needed when the actingoperation mode must be changed automatically, that is, there is a logic whichdrives these two inputs and setting group change based on the status informationfrom the circuit breakers.

The common Local/Remote (L/R) exclusion concerns the manual raising andlowering commands of OLATCC, that is, it internally proves the exclusionmechanism to prevent the remote commands (from SCADA) when the IED is inlocal mode.



9.5.8 Manual voltage regulationThe manual raising and lowering commands can be given either via theconfiguration inputs LOWER_LOCAL and RAISE_LOCAL, via the HMI of the IEDor via remote commands. The acting operation mode of OLATCC must be set to"Manual" and the Local/Remote control LR state monitored data of the IED has tobe "Local" to execute the control commands manually from HMI or viaconfiguration inputs. Although OLATCC is set to "Manual" but the LR state is setto "OFF" or "Remote", no manual control commands can be given.

For remote commands, the acting operation mode of the OLATCC function mustalso be set to "Manual" and the LR state monitored data has to be "Remote".

The manual raising or lowering commands can be given locally either via theManual control parameter ("Cancel"/"Lower"/"Raise") located in the HMI menuControl/OLATCC1 or via the configuration inputs LOWER_LOCAL orRAISE_LOCAL.

A raising command is given by selecting the enumeration value "Raise" and thelowering command is given by selecting the enumeration value "Lower". Anaccepted manual raising/lowering command activates the corresponding outputRAISE_OWN or LOWER_OWN to control the voltage of the own transformer.

Voltage control vs. tap changer moving directionOLATCC has the control settings Lower block tap and Raise block tap. The Lowerblock tap and Raise block tap settings should give the tap changer position thatresults in the lowest and highest controlled voltage value (usually at the LV side ofthe transformer). The setting of both Raise block tap value higher than Lower blocktap value and Lower block tap value higher than Raise block tap value is allowed.

When the value of Raise block tap exceeds the Lower block tap value, the raisecontrol activates the RAISE_OWN output. This results in raising the tap changerposition, and the measured voltage rises. Furthermore, the RAISE_OWN outputvalue is TRUE. If the own tap changer position is connected (that is, the own tapchanger's quality is good), the tap changer alarm is activated if the tap changer doesnot move upwards in the Cmd error delay time setting after the pulse activation,resulting that ALARM_REAS in the monitored data contains a command errorvalue. The Cmd error delay time setting default value is 20 seconds.

The lowering control works in a similar way, as shown in Figure 362. In the outputdata the LOWER_OWN output value is TRUE. An alarm is generated if the tapchanger does not move downwards in Cmd error delay time after the pulseactivation (assuming that the own tap changer position is connected).

In the second case, the parameters are set so that the value of Lower block tapexceeds the value of Raise block tap. The raising control activates theRAISE_OWN output. The result should be that the tap changer lowers its positionand the measured voltage rises. Furthermore, the RAISE_OWN output value isTRUE in the output data. If the own tap changer position is connected, the tap



changer alarm is activated if the tap changer does not move downwards in Cmderror delay time after the pulse activation, resulting that ALARM_REAS in themonitored data contains a command error value.

The lowering control works in a similar way, as shown in Figure 362. In the outputdata, the LOWER_OWN output value is TRUE. An alarm is generated if the tapchanger does not move upwards in Cmd error delay time after the pulse activation,assuming that the own tap changer position is connected.

9.5.9 Automatic voltage regulation of single transformerOLATCC is intended to control the power transformers with a motor-driven on-load tap changer. The function is designed to regulate the voltage at the secondaryside of the power transformer. The control method is based on a step-by-stepprinciple, which means that one control pulse at a time is issued to the tap changermechanism to move it exactly one position upwards or downwards. However,when intermediate steps are not indicated for the tap changer, it does not causealarm if more than one step change is met.

The purpose of the regulator is to maintain a stable secondary voltage of the powertransformer. The basis for this operation is the Band center voltage setting. Byincreasing or decreasing various compensation factors, the regulator calculates acontrol voltage from the band center voltage as shown in Equation 77. Hence, thecontrol voltage is the desired transformer secondary voltage to be maintained bythe regulator. The control voltage is compared to the measured voltage and thedifference between the two forms the regulating process error.

Since the tap changer changes the voltage in steps, a certain error has to beallowed. The error, called Band width voltage, is also set by the user. Arecommended setting for Band width voltage should be close to twice the stepvoltage of the transformer ΔUstep and never below it as a minimum. For example,Band width voltage is twice the value of ΔUstep in Figure 362.

If the measured voltage fluctuates within the control voltage ± half the Band widthvoltage setting, the regulator is inactive. If the measured voltage is outside the half-bandwidth voltage limits, an adjustable delay T1 (Control delay time 1 ) starts, asshown in Figure 362, where the lowering function is an example. The delay T1remains active as long as the measured voltage is outside the hysteresis limits ofhalf the value of Band width voltage. The factory setting for the hysteresis is 10percent of the set Band width voltage.



Bandwidth

voltage

U

ΔUstep

t

bandwidth limithysteresis limitUm, measured voltageUp, control voltage

T1 s

tart

T1 re

set

T1 s

tart

Low

er

T1

GUID-65BA0EC4-8E96-41E1-B273-3519DF5C25E1 V2 EN

Figure 362: Voltage-regulating function. A control pulse to lower the voltage isissued after the elapsed T1.

If the measured voltage is outside the hysteresis when the delay counter T1 reachesits setting value, the raising or lowering output relay is activated. This activateseither output pulse RAISE_OWN or LOWER_OWN, and the motor drive of the tapchanger operates. The status of these outputs can be read from the output dataRAISE_OWN or LOWER_OWN.

If the measured voltage falls or rises within the hysteresis limits during theoperating time, the delay counter is reset.

The pulse length can be defined with the LTC pulse time setting. The default valueis 1.5 seconds.

A short delay same as the typical tap changer operating time is active before thestart of the next operating timer is possible. For OLATCC, the delay is set to 6seconds. If one tap changer operation is not enough to regulate the transformervoltage within the hysteresis limits, a second adjustable delay T2 (Control delaytime 2), usually with a shorter time setting than T1, starts. This delay is used for thecontrol commands within the same sequence until the recovery of voltage occurs.The delays T1 and T2 can be selected either with definite or inverse timecharacteristics. In the inverse time mode operation, the operating time depends onthe difference between the control voltage and the measured voltage as shown inEquation 83. The bigger the difference in the voltage, the shorter the operatingtime. More information on the inverse time operation can be found in the OLATCCtimer characteristics chapter.

Regulation equationThe simple regulating principle is often complemented by additional features totake the voltage drop of lines into account (line drop compensation), coordinate theregulation of parallel transformers and change the voltage level according to the



loading state of the network. The control voltage Up is calculated according to theequation

U U U U Up s z ci rsv= + + −

GUID-86D55536-6EF1-43CB-BA21-EF57280DEBB4 V1 EN (Equation 77)

Up Control voltage

Us Set voltage level Band center voltage

Uz Line drop compensation term

Uci Circulating current compensation term

Ursv Voltage reduction parameter

Up can be directly read in the monitored data U_CTL.

The circulating current compensation term is calculated only in the parallel actingoperation modes "NRP" and "MCC".

Line Drop Compensation (LDC)The line drop compensation feature is used to compensate the voltage drop along aline or network fed by the transformer. The compensation setting parameters canbe calculated theoretically if the resistance and reactance of the line are known ormeasured practically from the line drop.

ILXLRL

UB UL

Load

GUID-552C931B-4A1A-4361-8068-0A151CB99F30 V2 EN

Figure 363: Equivalent electrical circuit for calculating the LDC term

The compensation parameters Line drop V Ris (Ur) and Line drop V React (Ux), arepercentage values of Un according to the equations.



Line drop V Ris UI R

U

Line dro

rCT n

VT n

= [ ] =× ×

× [ ]%_

_

3100

1

1

%Un

pp V React UI X

UUx

CT n

VT nn= [ ] =

× ×× [ ]% %

_

_

3100

1

1

GUID-B79F4E6B-B70E-4D85-BD8C-7877BD52A334 V1 EN (Equation 78)

ICT_n1 Nominal primary current of the CT

UVT_n1 Nominal primary voltage of the VT (phase-to-phase voltage)

R Resistance of the line, Ω/phase

X Reactance of the line, Ω/phase

The general LDC equation can be calculated.

UI

I

U Uz

injected

n

r x= ×

[ ] + [ ]( )[ ]

% cos % sinϕ ϕ

100 xUn

GUID-B004A188-862D-4015-868D-8654F8F5D214 V1 EN (Equation 79)

Iinjected Average of the currents I_A, I_B and I_C

Ur Setting Line drop V Ris

Ux Setting Line drop V React

φ Phase angle between U_A and I_A (ANGL_UA_IA in monitored data)

By default, the line drop compensation (LDC) is not active. LDC is activated bysetting LDC enable to "True". To keep the LDC term within acceptable limits in allsituations, OLATCC has a setting parameter LDC limit, which has a default valueof 0.10 xUn. As a result, this gives the maximum value for Uz in Equation 77.

If more than one line is connected to the LV busbar, the equivalent impedance iscalculated and given as a parameter setting as shown in Figure 363 for theequivalent electrical circuit for calculating LDC. For example, if there are Nnumber of identical lines with identical loads in the substation, the R- and X-valuesneeded for the settings Line drop V React and Line drop V Ris are obtained bydividing the resistance and the reactance of one line by N. Because the voltagedrop is different in lines with different impedances and load currents, it isnecessary to make a compromise when setting the Line drop V React and Line dropV Ris settings. Raising the voltage in the point of lowest voltage must not lead toovervoltage elsewhere.

By default, the line drop compensation is effective only on the normal active powerflow direction. If the active power flow in the transformer turns opposite, that is,from the regulated side towards the system in the upper level, the LDC term isignored, that is, set to zero. In such a case, it is assumed that the feeding units at theregulated side of the transformers maintain proper voltage levels. This can cause aconflict if the transformer tries to reduce the voltage at the substation. Additionally,



it is difficult to predict the actual voltage levels in the feeder lines in such a case,and lowering the voltage at the substation can have harmful effects in the far end ofthe network. However, the Rv Pwr flow allowed setting allows also negative LDCterms to be taken into equation.

The topology changes in the network can cause changes to the equivalentimpedance value of the network. If the change is substantial, the setting groups canbe used to switch between different setting values for Line drop V React and Linedrop V Ris. In practice this means that the boolean-type information from thetopology change is connected to the active setting group change.

The use of the LDC equation in the case of parallel transformers is described in theAutomatic voltage regulation of parallel transformers chapter.

Reduce Set Voltage (RSV) inputThe system frequency decreases when the active power production in the networkis smaller than its consumption. Either the power supply has to be increased orsome loads have to be shed to restore the power balance.

The simplest way to decrease the load is to reduce the voltage level by giving alower band center voltage value to the regulators. For this purpose, OLATCC hasthe setting group parameter Band reduction. The RSV input activation results inreduction. If this input is set to TRUE, a set target voltage value is decreased byBand reduction. If more than one RSV reduction steps are desired, the setting groupchange has to be used where different Band reduction values are supported. Thedecreased value is kept as a target value as long as the RSV input is TRUE.

Because the decrease of frequency indicates a need to reduce the load, it ispractical to connect the start signal of an underfrequency function block to the RSVdigital input.

It depends on the load characteristics how much the load is reduced as the voltagedrops. For instance, purely resistive loads are proportional to the square of thevoltage, whereas motor drives based on frequency controllers may draw constantpower despite small voltage changes.

The status of the RSV input can be read from the RSV input data.

9.5.10 Automatic voltage regulation of parallel transformersIt is likely that a circulating current between transformers occurs if two or moretransformers with slightly different ratios are energized in parallel. This is due tothe unbalanced short circuit impedances of the parallel transformers. To avoid suchcurrents, the tap changers of the transformers should be adjusted to achieveequilibrium. If the transformers are assumed identical, the tap (voltage) steps andtap positions should also match. In this case, the Master/Follower principle can beused. However, unequally rated transformers with different tap steps can beconnected in parallel and these configurations can also be managed by the tapchanger control function. For these configurations, the Minimizing Circulating



Current (MCC) or Negative Reactance Principle (NRP) should be used. The MCCand NRP principles are also suitable for identical transformers.

The circulating current, which is almost purely inductive, is defined as negative ifit flows towards the transformer. Uci in Equation 77 is positive and the controlvoltage Up rises as a result to the RAISE_OWN output signal activation if thecirculating current level is sufficient (Equation 80 and Equation 82) and the otherparameters remain the same. As a result, the voltage rise should diminish thecirculating current.

LDC equation and parallel connectionThe additional challenge in the parallel connection regarding the line dropcompensation is to know the total current which flows through the paralleltransformers.

In the Master/Follower mode, it is easier to know the total current than in otherparallel modes since the transformers are assumed to have identical ratings, that is,the total current (Iinjected in Equation 79) is obtained by multiplying the measuredload current (the average of the secondary currents I_A, I_B and I_C of theconnected own transformer) with the number of parallel transformers. OLATCCcan internally conclude the number of parallel transformers from the connected tapchanger position inputs. However, if there is no connected position informationfrom the other parallel transformers, the correct number of the paralleltransformers, excluding the own transformer, needs to be set with the Paralleltrafos setting.

In the MCC mode, the horizontal communication transfers the information fromthe measured load currents between the regulators so that the total current neededin the line drop compensation can be summed accurately. Here, Iinjected is definedto be the phasor sum of all the parallel power transformer secondary-side currents.The currents from other transformers must be fed via the TRx_I_AMPL andTRx_I_ANGL inputs.

In the NRP mode, the parallel transformers have different ratings and there is nocommunication between the regulators. Therefore, when setting Line drop V Reactand Line drop V Ris, the ICT_n1 used in the equation should be the sum of the ratedcurrents of all the transformers operating in parallel. Here, Iinjected is also defined asthe average of the connected secondary currents (I_A, I_B and I_C). The calculatedline drop compensation value can be read from the monitored data LDC.

9.5.10.1 Master/Follower principle M/F

The Master/Follower (M/F) operation principle is suitable for power transformerswith identical ratings and step voltages. One voltage regulator (master) measuresand controls and the other regulators (followers) follow the master, that is, all thetap changers connected in parallel are synchronized. This parallel operation isobtained by connecting the FLLWx_CTL output of the master to the correspondinginput TAPCHG_FLLW of the followers via a horizontal GOOSE communication.



The values for the FLLWx_CTL command are 1=Lower follower x and 2=Raisefollower x. Consequently, the values for the TAPCHG_FLLW command are1=Lower and 2=Raise.

If several regulators are to act as masters (one at a time), their outputs also have tobe routed to the inputs of other regulators. To start the parallel operation, themaster regulator is set to the "Auto master" mode and the followers to the "Autofollower" mode. To implement this setting, a group changing has to be planned.

To keep all the tap changers in the same position, the master needs to know the tappositions of the followers. This way, the circulating current is kept at its minimum.The position values of the followers can be brought to the master either via thehorizontal GOOSE communication or TPOSSLTC.

If it is not possible to use horizontal communication between the IEDs and theposition information cannot be wired from the parallel transformers, the M/Fprinciple can still be used to regulate two or an unlimited number of transformersin parallel. Since the master cannot detect the tap positions of parallel transformers,it just activates the lowering and raising outputs for all the followers when itcontrols its own tap changer. This is called blind control. In this case, a number ofparallel transformers are regulated as one unit. The tap position inputs 1…3(TR1_TAP_POS..TR3_TAP_POS) must be left unconnected for the master toknow that the tap positions of the followers are unknown. The time delay betweensuccessive commands can be set by the Follower delay time setting. The defaultvalue is six seconds.

When a disconnected transformer is taken into use and the tap position is unknown,the follower should be manually controlled to the same position as the master. Thiscan also take place in the master/follower mode. First, the master gives a controlcommand to its own transformer, that is, it is echoed to the followers (the followertap positions have to be connected). Thereafter, successive control commands tothe followers take place until the master and followers have the same tap positions.

Out-of-step functionThe out-of-step function is usually used in the M/F modes only. The out-of-stepfunction means that the master is able to detect the position values of the followersand control them to the same position as the master is. In this case, the masterassumes that the followers also have either Raise block tap higher than Lowerblock tap or Lower block tap higher than Raise block tap because this defines whatis the given command pulse for a follower. If the master has Raise block tap higherthan Lower block tap and the follower has Lower block tap higher than Raise blocktap, the corresponding TAPCHG_FLLW included control signals should beconnected crosswise. This requires an extra logic where dual-point command bitshave to be converted, that is, 0=>0, [01]=1=>[10]=2 and [10]=2=>[01]=1.

M/F is the only parallel mode which has an out-of-step functionality. In the MCCand NRP operation modes, the circulating current is minimized, which mostprobably means different tap positions in the parallel transformers. Moreover, thesemodes allow different ratings and step voltages for the parallel transformers.



Therefore, it is reasonable to apply the out-of-step function only to the M/Foperation mode.

The out-of-step function is triggered when the master detects a difference of atleast one step between the tap changer positions in the follower and in the master.The master then sends special raising or lowering commands to the divergedfollower. If two consecutive commands fail to change the position of the followerto the right direction, the master activates the PAR_FAIL output, that is,PAR_FAIL is set to TRUE, and stops the special recovery efforts. However, everytime the master controls its own tap changer later, it always sends a controllingpulse to the diverged follower too. Furthermore, if the master notices a correctposition change after a sent pulse, it restarts the attempt to drive the follower to thesame position and deactivates the PAR_FAIL output, that is, PAR_FAIL is set toFALSE. However, if there still are diverged followers, the reset is not indicated. Itis indicated only when no diverged followers exist. Monitoring, and hence theindication of a paralleling failure, is not possible in blind control. The followerswith a parallel failure can be read from the monitored data FAIL_FLLW. Forexample, if only follower 3 is in the parallel failure state, FAIL_FLLW has thevalue "Follower 3". If both followers 1 and 2 are in the parallel failure state,FAIL_FLLW has the value "Followers 1+2". By default, when no failed followersexist, the value is "No failed followers".

9.5.10.2 Negative Reactance Principle NRP

This parallel control scheme is suitable for power transformers with differentratings and step voltages. Since no communication between the regulators isneeded, this principle can be applied even when the parallel transformers arelocated at different substations. To start the parallel operation, the acting operationmode has to be set to "NRP" for all the regulators of the connection. The actingoperation mode can be changed via function block inputs or by setting eitherlocally or remotely.

When applying this principle, each regulator has a phase angle setting φLoad(setting parameter Load phase angle) towards which it tries to regulate the current.The setting value is chosen according to the expected power factor of the load(positive setting value equals inductive load). When the actual phase angle of theload current is the same as the setting and the transformers and their tap changerpositions are identical, the currents of the two or more transformers are in the samephase as the total load current. If the tap changer positions are different, thecirculating current flows and the currents of different transformers either lag orlead the load current. Figure 364 shows that the circulating current is the reactivecomponent which separates the measured current vector from the expected anglevalue.



ILOAD x sin(φLOAD)

ITR1 x sin(φ1)

φLOAD

φ1

U_A

Ici = circulatingcurrent

ILOAD

ITR1

ILOAD = ITR1 x cos(φ1)/cos(φLOAD)

GUID-2B71B160-FB76-4BE0-952F-75F42220401F V2 EN

Figure 364: The expected phase angle of the load supplied by the transformersoperating in parallel is entered as a setting value φLoad

The regulators calculate the circulating current with the equation

I Ici Load TR= − × ×(sin tan cos )ϕ ϕ ϕ1 1 1

GUID-823FAEEA-589B-4C8E-81CD-E5FECF28BF06 V1 EN (Equation 80)

ITR1 Average of the currents I_A, I_B and I_C

φ1 Phase angle between U_A and I_A

φLoad The set Load phase angle of the load current

In the negative reactance method, the circulating current is minimized by changingthe control voltage according to the measured circulating current. The regulatorcalculates the circulating current compensation term Uci using the equation

UI

I

StabilityUci

ci

nn=

−× ×

100

GUID-2A7864D3-D59F-47F9-84FD-B3F2C15178EB V1 EN (Equation 81)

Ici Circulating current

Stability Stability setting (the recommended value depends on the loop impedance)

If the transformers operating in parallel have different rated currents, the value ofthe Stability factor setting of the regulator should be proportional to the ratedcurrents, that is, the higher the rated current, the higher the Stability factor settingvalue.



By comparing the reactive components of the currents measured by the differentregulators it is possible to find out if the circulating current has been minimized.The circulating current is minimized when the reactive components are equal.

The negative reactance method gives satisfactory results only if the phase angle ofthe load current is known relatively accurately. If the actual phase angle deviatesfrom the phase angle setting, a regulating error occurs. However, for the caseswhere there is an occasional stepwise change in the phase angle of the load, theregulating error can be suppressed with the logic. This kind of stepwise change canoccur, for example, when a capacitor bank is switched on to compensate a reactivepower flow.

Another possibility is to use an automatic setting group change between settinggroups in different loading situations. The setting groups then have different setvalues for the load phase angle.

9.5.10.3 Minimizing Circulating Current principle MCC

The MCC principle is an optimal solution for controlling the parallel transformersof different ratings or step voltages in substations with varying reactive loads.Since this control scheme allows the exchange of data between regulators, thecirculating current can be calculated more accurately than with other schemes.However, a maximum of four regulators can be connected in parallel. To start theparallel operation, the acting operation mode parameter has to be set to "MCC" forall the regulators of the connection. Furthermore, the signal CON_STATUS mustindicate that the transformers are connected to the network. A unit that isminimizing the circulating current must have the acting operation mode set to"MCC". However, units that have the acting operation mode set to "Manual" do notperform any circulating current minimization operations themselves.

2 x Ici

ITR1 x sin(φ1)

ITR2 x sin(φ2)

φ1

φ2

U_A

Ici = circulating current

ITR1

ITR2

GUID-F73692B0-629D-4C0A-BFAB-648B0A832E42 V2 EN

Figure 365: The circulating current between two parallel transformers



In this case, the circulating current can be calculated with the equation

II I

ciTR TR

=× − ×(sin sin )φ φ1 1 2 2

2GUID-5898550F-0095-4173-91ED-4D5AFFC7B58D V2 EN (Equation 82)

ITR1 Average primary value of the currents I_A, I_B and I_C measured by regulator 1

ITR2 Average primary value of the currents I_A, I_B and I_C measured by regulator 2

φ1 Phase angle between U_A and I_A in regulator 1

φ2 Phase angle between U_A and I_A in regulator 2

The circulation current can be read from the monitored data I_CIR.

Using the circulating current, the compensation term Uci can be calculated with theequation

UI

IUci

ci

CT n

n=−

× ×

_ 1 100

Stability

GUID-173A1FA0-8C07-4BA8-AAEB-62F95E10396C V2 EN

Ici Circulating current, primary value

ICT_n1 Nominal primary current of the CT

Stability factor Stability setting (the recommended value depends on the loop impedance)

Using the circulating current, a compensation term Uci can be calculated usingEquation 81. The value of Uci, which can be positive or negative, is considered byadding it to the Band center voltage Us (Equation 77). According to Figure 365 andEquation 82, the phasor information from the other IEDs is needed.

Parallel unit detection and the MCC modeThe network connection status information is essential for the MCC operationmode. The status FALSE needs to be connected to the CON_STATUS input toensure a proper operation of the MCC calculation if the transformer is disconnectedbut OLATCC remains in the MCC mode. This way the disconnected transformer isexcluded from the circulating current calculations.

The CON_STATUS input is used to identify if a certain transformer controller isable to send the current information to other transformer controllers for circulatingcurrent minimization purposes. As a result, this input has effect only in the MCC orManual acting operation modes. In these modes, if CON_STATUS is TRUE, theinformation transmission is started. The circulating current information receiving isallowed only in the MCC acting operation mode when CON_STATUS is TRUE.PAR_UNIT_MCC can be seen in the monitored data view.



Communication and the MCC modeThe phasor information from the other parallel IEDs is needed for the circularcurrent calculation. Therefore, horizontal GOOSE communication is neededbetween IEDs when the MCC principle is used.

The transferred current phasor contains the primary value of the measured current.The received current phasor information can be read from the input dataTRx_I_AMPL and TRx_I_ANGL for the magnitude and angle respectively. Thevalue "x" gives the connected parallel transformer number, a value between 1 and 3.

The sent phasor information always represents the difference between the voltagephasor U_A and I_A. This information regarding the current phasor can be readfrom the output data TR0_I_AMPL and TR0_I_ANGL. The allowed actingoperation modes for sending data are MCC or Manual, both with the inputCON_STATUS activated. The communication can be seen to be active when thesent and received phasor magnitude is not clamped to zero. The communicationphasor magnitude found to be zero results either from a rejected acting operationmode or too low signal magnitudes (OLATCC Voltage and current measurementschapter). Active CON_STATUS indicates that the corresponding transformer isconnected to network and its current affects the circular current of othertransformers even when it is itself in the manual operating mode.

9.5.11 Timer characteristics

Operation timer functionalityThe delay times can be set to follow either the definite time characteristic or theinverse time characteristic with the Delay characteristic setting. By default, the"Definite time" type is selected. The timer mode cannot be changed between cyclesT1 and T2, only either before T1 has started or after T2 has elapsed.

Table 580: Different timer mode delays

Timer mode Setting DescriptionT1 Control delay time 1 First delay when the measured voltage

exceeds or falls below the limit value.

T2 Control delay time 2 Second delay when the first control didnot bring the measured voltage to adesired level.

The delay after the command pulse activation and the restart of the timer is sixseconds. The delay is assumed to be the tap changer operating delay. The timerstatus can also be read from the monitoring data TIMER_STS, where T1 activegives a value "Lower timer1 on" or "Raise timer1 on" while T2 active gives a value"Lower timer2 on" or "Raise timer2 on". Furthermore, the "Fast lower T on" valueindicates that the fast lowering control functionality is active (Blocking schemechapter).

Activation of operation timer also activates the TIMER_ON output.



IDMT type operationThe IDMT timer can be selected by setting Delay characteristic to "Inverse time".The minimum time at the inverse time characteristic is limited to 1.0 second.However, the minimum recommended setting of the control delay times T1 and T2is 10 seconds when the definite time delay is used and 25 seconds when the inversetime delay is used.

The inverse time function is defined by the equations:

BU

U

d

BW

=

( / )2

GUID-59DE8DA1-7C1D-41A2-98A8-48A91D061FFD V1 EN (Equation 83)

Ud |Um – Up|, differential voltage

UBW Setting parameter Band width voltage

tT

B=

−( )2

1

GUID-18A433AA-B4A7-4DA8-94B2-4FDF12A23FD1 V1 EN (Equation 84)

T T1 or T2

The monitored data UD_CTL shows the differential voltage value Um – Up. If thevalue exceeds half of the Band width voltage setting and has a negative sign, araising pulse is issued. The UD_CTL monitored data can also be seen in the DTtimer mode.

The hysteresis approach is presented in Figure 362.



GUID-6AA3C028-E7DD-4C87-A91C-4B8B1D43CBBA V2 EN

Figure 366: Inverse time characteristic for different values on T1 or T2 (Thesmaller figure is a zoom-in of the larger one)

9.5.12 Pulse controlThe tap changer generates an active operating signal when the tap-changingprocess is active. This signal is to be connected to the TCO input. The signal is usedfor alarming purposes. If the signal is active (=TRUE) for more than 15 secondsafter the control pulse has been deactivated, an alarm is generated (Alarmindication chapter). If the TCO input is not connected, no alarm is generated.

The control operation is disabled when the TCO input signal is active, unless no tapchanger stuck is detected (Alarm indication chapter). Thus, it is not possible forthe controller to send new pulses to the tap changer when it is already operating.This is because the tap changers are typically immune to new pulses when they areoperating. Furthermore, because the pulses are omitted, the tap changer pulsecounter of the controller is not incremented either.

The commands are not tolerated during an active pulse. Therefore the commandpulse length (setting LTC pulse time) has to be carefully selected, although anactive TCO input is used internally to prevent new commands from reaching the tapchanger.

To be more certain that no new pulses are to be sent when the tap changer is inoperation, the tap changer operating signal can also be connected to the



LTC_BLOCK input. In this case, the external blocking is achieved when anautomatic pulse is sent to the operating tap changer. The external LTC_BLOCK hasby default no effect when the acting operation mode is set to "Manual".

The status of the TCO input can be read from the TCO input data.

9.5.13 Blocking schemeThe operation of the voltage regulator can be blocked for several reasons. Thepurpose of blocking is to prevent the tap changer from operating under conditionsthat can damage the tap changer or exceed other power system-related limits. Thereis the BLK_STATUS monitored data that does not imply actual blocking butreveals if the coming command pulse is issued or not. The blocking itself happenswhen the corresponding bit in the signal BLK_STATUS is active and the commandpulse is to be started due to a timer elapse or a local command. This is to avoidunnecessary event sending.

The cross (X) in the table defines when the operation is blocked (if thecorresponding bit is active in BLK_STATUS). For example, an overvoltage(runback raising voltage) results in blocking only when the acting operation modeis "Manual" and the manual raising command is to be given.

Table 581: Default blocking schema in OLATCC

Actingoperationmode

Command Loadcurrent

Blockloweringvoltage

Runbackraisingvoltage

Highcirculatingcurrent

ExternalBlock

Extremepositions

Manual Raise X X X

Lower X X

Autofollower

Raise X X X X

Lower X X X X

Autosingle,Automaster,NRP,MCC

Raise X X X1) X X2)

Lower X X X1) X X2)

1) Because the circulating current is only calculated in the NRP and MCC modes, it can have ablocking effect only in these modes.

2) However, in these cases pure automatic operation notices that the extreme position has alreadybeen reached and there is no need to activate the signal for data set event sending. The automaticfollower case can here be compared to a manual case and an event can be sent, that is, thecorresponding output is activated.

In addition to the default blocking, the Custom Man blocking setting has beenadded due to different operation practices considering the manual commandblocking. The setting can be used to adapt blockings considering the manualovercurrent, undervoltage or external blocking. (The blockings are in the table incolumns Load current, Block lowering voltage and External block for the manualoperating mode.) The default value for the parameter is "OC". This means that the



table explaining the default blocking schema operates as such. However, there arealso other alternatives that cause different operation when compared to that table.

Table 582: Customized manual blocking schema

Manualblockingtype

Enumeration Description

1 Custom disabled No Load current, blocking of lower (under) voltage or externalblocking have effect in the manual.

2 OC Load current blocking has an effect in the manual operation mode

3 UV Block lowering (under) voltage blocking has an effect in themanual operation mode

4 OC, UV Conditions 2 and 3 together: Load current and block lowering(under) voltage blocking have effect in the manual operation mode

5 EXT External blocking has an effect in the manual operation mode

6 OC, EXT Conditions 2 and 5 together: Load current and external blockinghave effect in the manual operation mode

7 UV, EXT Conditions 3 and 5 together: Block lowering (under) voltage andexternal blocking have effect in the manual operation mode

8 OC, UV, EXT All conditions 2, 3 and 5 together: Load current and blocklowering (under) voltage and external blocking have effect in themanual operation mode

If the Custom Man blocking setting is "Custom disabled", the blocking schemaregarding the acting operation mode "Manual" is as given in Table 583. Otheroperation modes follow the default schema.

Table 583: Blocking schema for selection "Custom disabled"

Actingoperationmode

Command Loadcurrent




ExternalBlock

Extremepositions

Manual Raise X X

Lower X

Table 584: Blocking schema for selection "OC, UV, EXT"

Actingoperationmode

Command Loadcurrent




ExternalBlock

Extremepositions

Manual Raise X X X X X

Lower X X X X



Table 585: Blocking schema for selection “UV, EXT”

Actingoperationmode

Command Loadcurrent




ExternalBlock

Extremepositions

Manual Raise X X X X

Lower X X X

Load currentThe load current blocking is mainly used for preventing the tap changer fromoperating in an overcurrent situation. For example, if the current is not high enoughto activate the protective IED of the substation, it can still be fatal for the diverterswitch of the tap changer. This operation can be adjusted with the setting parameterLoad current limit. The maximum of measurements from the secondary-sidecurrent phases is used for blocking. By default, both the automatic operation andthe manual operation are blocked (Table 581) when the set limit is exceeded.

The blocking status can be read from the monitored data BLKD_I_LOD.

Block lowering voltageThe block lowering voltage feature blocks both raising and lowering voltagecommands if the measured voltage is too low to be corrected by operating the tapchanger. Such a situation can occur due to a faulty measuring circuit, an earth faultor an overcurrent situation. By default, only the automatic (also automaticfollower) operation is blocked when the undervoltage condition is met (Table 581).This operation can be adjusted with the setting parameter Block lower voltage.

The blocking status can be read from the monitored data BLKD_U_UN.

However, there is no minimum limit for the undervoltage blocking. The blocking isallowed even if the measured voltage is not connected or it has temporarily a verylow value. There is a minimum limit for the phase angle calculation based on thevoltage phasor magnitude.

Runback raising voltageThe manual raising command is blocked if the overvoltage limit is exceeded (Table581). However, in the automatic operation mode, the overvoltage situation triggersthe fast lowering feature. More information can be found in the Manual voltageregulation chapter. This operation can be adjusted with the setting parameterRunback raise V.

The blocking status can be read from the monitored data RNBK_U_OV.

High Circulating CurrentThe circulating current value is calculated in the operation modes NegativeReactance Principle (NRP) and Minimizing Circulating Current (MCC). Only theautomatic operation in these modes is blocked when the high circulating current is



measured (Table 581). This operation can be adjusted with the setting parameterCir current limit.

The blocking status can be read from the monitored data BLKD_I_CIR.

LTC_BLOCK – external block inputWith the PCM600 tool configuration possibilities, a desired blocking condition canbe built by connecting an outcome to this input. The blocking status can be readfrom the monitored data BLKD_LTCBLK. When activated, this input blocks onlythe automatic operation of the regulator by default (Table 581). For the fullyautomatic modes, the signal activation resets the timer, and the monitored dataBLKD_LTCBLK is not activated.

Extreme positionsThis blocking function supervises the extreme positions of the tap changer. Theseextreme positions can be adjusted with the setting parameters Raise block tap andLower block tap. When the tap changer reaches one of these two positions, thecommands in the corresponding direction are blocked (Table 581). Here it dependson the comparison between the Raise block tap and Lower block tap settings,which direction is blocked (Voltage control vs. tap changer moving directionsection). This blocking affects both the automatic and manual operation modes.

However, as shown in Table 581, no blocking indication is to be generated in thefully automatic modes. Here "Auto follower" is not a fully automatic mode. Theunconnected position information does not cause the total block of OLATCC, onlythe extreme position blocking is not working.

The blocking status can be seen in the generated events.

Fast lowering controlOLATCC provides the fast lowering control in the automatic operation modes.When the set Runback raise V is exceeded, the regulator gives fast lowering controlpulses until the voltage drops below the specified limit. This fast lowering controlcan be seen with the monitoring data TIMER_STS, where the value "Fast lower Ton" indicates this functionality to be active.

To allow the fast lowering operation, Runback raise V has to be setalways to a value higher than the control voltage (U_CTL) plus halfof Band width voltage.

Typically, the blockings are reset when the corresponding limit with the hysteresisis undershoot or exceeded. Although blocking is reset after undershooting the above-mentioned limit, the fast lowering control operation continues until the measuredvoltage signal difference undershoots half the Band width voltage hysteresis limit(Figure 362). As a result, normal automatic mode operation is not possible beforethis happens.



Fast lowering control causes successive LOWER_OWN pulses to be activated. Thetime between consecutive pulse starts is the pulse length plus 1.5 seconds.

• There is no tap changer operating delay (otherwise six seconds) taken intoaccount in this cycle (meaning that some command pulses are ineffective dueto tap changer operation, as described in the Pulse control chapter)

• Timer mode set by Delay characteristic has no effect here (always the DT timer-type operation). Because the minimum pulse length (the LTC pulse timesetting) is 0.5 seconds, the shortest interval between successive pulses can betwo seconds.

In the automatic follower mode, the fast lowering is not triggered. In this way, theawkward dispersion of position values in different units can be avoided. Themaster always decides on the fast lowering on behalf of the follower units.Moreover, master and follower should measure an equal voltage level and havesimilar setting values for the overvoltage blocking limit.

9.5.14 Alarm indication

Tap Changer MonitoringOLATCC supervises the operation of the tap changer and alarms if the alarmcondition is detected. An alarm activation means that the ALARM output isactivated and the alarm reason can be read from the monitored dataALARM_REAS. Alarms are in use by default but they can be set not to be in useby setting Alarms enabled to "False". Three different alarm conditions and theircombinations can be detected by OLATCC.

Command errorOLATCC supervises the tap changer position information of the own transformerwhen a control pulse is given. If the correct position change (direction depends onthe comparison of the settings Raise block tap and Lower block tap) is not seen byOLATCC in Cmd error delay time after the pulse start, the alarm is issued.

If the position information is not connected, no alarm is generated. The alarm isreset when the correct change in position value is detected after a given pulse or ifa new command pulse is given.

The monitored data ALARM_REAS is set during an alarm. This means that if thealarm reason is active, ALARM_REAS has the value "Cmd error".

TCO signal failsIf the tap changer operating signal TCO stays active for more than 15 seconds afterthe output pulse deactivation, OLATCC concludes this as an abnormal conditionand assumes that the tap changer is stuck. The alarm is reset when the TCO inputsignal deactivates. The monitored data ALARM_REAS is set during the alarm.This means that only if alarm reason is active, ALARM_REAS has the value "TCOerror".



If the TCO input signal is not connected (indicated by bad quality), this type ofalarm is not possible.

Regulator pumpingIt is possible that faulty settings cause the regulator to give control pulses toofrequently. For example, too low a setting for the Band width voltage (Figure 362)can result in a pumping condition where the regulator has problems to bring theregulated voltage to a desired level. To detect this, OLATCC has a setting Maxoperations in 1h, which defines the allowed number of lowering and raisingcommands during a one-hour sliding time window. The detection is active both inthe manual and automatic operation modes. The alarm is reset after the countednumber of the operations during the one-hour time window is less than the setvalue. The number of executed operations per last one hour can be read from themonitored data OP_TM_NUM_H. However, this parameter is updated only in three-minute intervals. Again, the monitored data ALARM_REAS is set during an alarm.This means that only if alarm reason is active, ALARM_REAS has the value"Pump error".

The operation of OLATCC is not blocked during an alarm situation, but all thealarms mentioned above cause the automatic operation to be delayed. In practice,this means that the set delay times T1 and T2 are doubled.

In addition to the alarm detections, OLATCC provides a nonvolatile operationcounter parameter (monitored data OPR_CNT) for determining the serviceintervals of the tap changer. The counter gives the total number of raising andlowering commands given in the manual and automatic modes. All commands,even those that are omitted by the tap changer due to its operation sequence, arecalculated in a cumulative counter. This data parameter can be reset via the clearmenu parameter OLATCC counter.

9.5.15 ApplicationOLATCC is used to control the voltage on the load side of the power transformer.Based on the measured voltage and current, the function block determines whetherthe voltage needs to be increased or decreased. The voltage is regulated by theraising or lowering commands sent to the tap changer.

The basic principle for voltage regulation is that no regulation takes place as longas the voltage stays within the bandwidth setting. The measured voltage is alwayscompared to the calculated control voltage Up. Once the measured voltage deviatesfrom the bandwidth, the delay time T1 starts. When the set delay time has elapsed,a raising or lowering control pulse is sent to the tap changer. Should the measuredvoltage still be outside the bandwidth after one tap change, the delay time T2 starts.T2 is normally shorter than T1.

Under certain circumstances, the automatic voltage regulator needs to be enhancedwith additional functions such as Line Drop Compensation (LDC) and Reduce SetVoltage (RSV). Also, various parallel operation modes are available to fit



applications where two or more power transformers are connected to the samebusbar at the same time. The parallel operation modes of OLATCC are Master/Follower (M/F), Minimizing Circulating Current (MCC) and Negative ReactancePrinciple (NRP).

Configuration example for the Manual and Auto single modes

M

U12b

IL1b, IL2b, IL3b

VT_

CT_

IED

TCO LOWER RAISE

+ +-

+

TAP_POS

Tap position indication (e.g. mA -signal)

-

+Auto /

Manual

-

+Lower

-

+Raise

AUTO RAISE_LOCALLOWER_LOCAL

GUID-88A1D370-2203-48CA-9843-76C309B4049D V4 EN

Figure 367: Basic connection diagram for the voltage regulator



T_F32_INT8F32 INT8

TPOSSLTCBI0BI1BI2BI3BI4BI5SIGN_BITTAP_POS

OLATCCI_AI_BI_CU_ABTR1_TAP_POSTR2_TAP_POSTR3_TAP_POSRAISE_LOCALLOWER_LOCALTAPCHG_FLLWPARALLELAUTOCON_STATUSLTC_BLOCKTCORSVTR1_I_AMPLTR1_I_ANGLTR2_I_AMPLTR2_I_ANGLTR3_I_AMPLTR3_I_ANGL

RAISE_OWNLOWER_OWN

FLLW1_CTLFLLW2_CTLFLLW3_CTL

BLKD_I_LODBLKD_U_UNBLKD_U_OVBLKD_I_CIR

BLKD_LTCBLKALARM

PAR_FAILPARALLEL

AUTOTIMER_ON

TR0_I_AMPL*TR0_I_ANGL*

IL1bIL2bIL3bU12b

BI6_AUTO

BI1_TCO

TAP_POS value is transferred from TPOSSLTC to OLATCC automatically

PO2_RAISE_OWN

PO1_LOWER_OWN

TAP_POS

X130 (RTD).AI_VAL1

BI3_LOWER_LOCAL

BI4_RAISE_LOCAL

* Only for GOOSE Engineering

GUID-CA9CF06F-2ADB-4758-B527-EE4400B35B36 V2 EN

Figure 368: Configuration example for the Manual and Auto single modes

The configuration example uses an mA signal to indicate the current tap position ofthe local transformer. To take that position information to OLATCC, the measuredmA signal is first scaled with the X130 (RTD) function. The scaled value is thenconverted to integer value with T_F32_INT8 function. That integer value isconnected to the TAP_POS input of the TPOSSLTC function. The tap positionvalue is automatically transferred from TPOSSLTC to OLATCC without aconfiguration connection.

Configuration example for the Auto parallel (Master/Follower) modeThe configuration example for Master/Follower describes how the tap positioninformation is transferred from follower to master with the horizontal GOOSEcommunication. The status information from circuit breakers and an extra logic canbe used to change the operation mode via inputs of the master and the follower(Operation mode = "Input control").



M

U12b

IL1b, IL2b, IL3b

TCO

Tap position ind.

Raise

Lower

M

U12b

IL1b, IL2b, IL3b

TCO

Tap position ind.

Raise

Lower

Regulator 1 signals Regulator 2 signals

CB1 CB3

CB2CB2

Lowerfollower

Raisefollower

GUID-0B2CBB09-9B4C-498A-BB1C-3A3689513BDF V2 EN

Figure 369: An example of the configuration for the Auto parallel (Master/Follower) mode (the position of the follower known by the master)

AND

CB1

CB2

CB3


RAISE_OWNLOWER_OWN



BLKD_LTCBLKALARM

PAR_FAILPARALLEL

AUTOTIMER_ON


AND

ANDCB1

CB2

CB3


RAISE_OWNLOWER_OWN



BLKD_LTCBLKALARM

PAR_FAILPARALLEL

AUTOTIMER_ON


AND

AND

NOT

GOOSE communication ( Raise / Lower follower )

IED 1 / Regulator 1 (Master)

IED 2 / Regulator 2 (Follower)

GOOSE communication

( Regulator 2 tap position )

* Only for GOOSE Engineering * Only for GOOSE Engineering

GUID-CE09E39C-D02B-4978-B968-B5B2EA19DB69 V2 EN

Figure 370: Simplified regulator 1&2 configurations of the Master/Followerexample



Table 586: The automatic selection of operation modes for regulators in the Master/Followerexample

CB1 CB2 CB3 Regulator 1 Regulator 2Open Open Open Manual Manual

Open Open Closed Manual Auto single

Open Closed Open Manual Manual

Open Closed Closed Manual Auto single

Closed Open Open Auto single Manual

Closed Open Closed Auto single Auto single

Closed Closed Open Auto single Manual

Closed Closed Closed Auto parallel(Master)Auto parallelmode = "Automaster''

Auto parallel(Follower)Auto parallelmode = "Autofollower"

Configuration example for the Auto parallel (MCC) modeThe purpose of the Auto parallel (MCC) mode is to minimize the circulatingcurrent between the parallel transformers. The data exchange between theregulators can be done with the horizontal GOOSE communication.


RAISE_OWNLOWER_OWN



BLKD_LTCBLKALARM

PAR_FAILPARALLEL

AUTOTIMER_ON



RAISE_OWNLOWER_OWN



BLKD_LTCBLKALARM

PAR_FAILPARALLEL

AUTOTIMER_ON


IED 1 / Regulator 1 IED 2 / Regulator 2

GOOSE communication

GOOSE communication

* Only for GOOSE Engineering * Only for GOOSE Engineering

GUID-1D6F1FD5-58AD-4AB1-B3F4-3414392CFEE1 V2 EN

Figure 371: Two parallel transformers and the horizontal connection viaGOOSE to transfer current and the phase angle information whenthe MCC principle is used

Configuration example for the Auto parallel (NRP) modeThe advantage of the Negative Reactance Principle (NRP) operation mode is thatno wiring or communication is needed between the IEDs. The voltage regulatorsoperate independently. However, for the cases where there is an occasional



stepwise change in the phase angle of the load, the regulating error can besuppressed by an automatic setting group change or by changing the operationmode with the logic.


RAISE_OWNLOWER_OWN



BLKD_LTCBLKALARM

PAR_FAILPARALLEL

AUTOTIMER_ON


NOTCapacitor bank

connected

FALSE => Auto parallel (NRP)

TRUE => Auto single

* Only for GOOSE EngineeringGUID-20F51931-FED1-4E58-8BBD-4B94702F0E2A V2 EN

Figure 372: Changing the operation mode of OLATCC automatically when thecapacitor bank is connected

Comparison summary between parallel operation modesThe parallel operation modes are needed because if the parallel regulators operatedindependently, at some point the transformers would become out of step with eachother.

The circulating current would increase and the line drop compensation would thusincrease for the transformer giving the highest voltage. Correspondingly, theincreasing circulating current would cause the transformer giving the lowestvoltage to decrease the voltage due to a decreased line drop compensation effect. Inother words, the two transformers would run apart.

However, it is case-specific which parallel operation mode is the most suitable.



Table 587: Different parallel operation modes

Parallel operation modes DescriptionMaster/Follower (follower positions not known bymaster)

Requires power transformers with identicalratings and step voltages- Extra wiring work: raising/lowering commands(input TAPCHG_FLLW connected from outputFLLWx_CTL) from the master to the follower- Manual control needed in the beginning ofoperation- Blind control: follower positions after controlcannot be supervised. It must be relied on thatthe followers are following the commands.+ Parallel transformers are regulated as one unit+ Supports an unlimited number of transformersin parallel

Master/Follower (follower positions known) Requires power transformers with identicalratings and step voltages.- Extra wiring work:raising/lowering commands (the TAPCHG_FLLWinput connected from the FLLWx_CTL output)from the master to the followerTAP_POS connections from the followers to themaster- Supports not more than four transformers inparallel.

Negative reactance principle The actual phase angle setting results in aregulating error. When the line dropcompensation is used, the setting should bechanged when the number of transformers inparallel operation is changed.+ The step voltages and short circuitimpedances of the transformers do not need tobe identical.+ No communication or wiring betweenregulators is needed, meaning that the principlecan be applied even when the paralleltransformers are located at different substations.+ Supports an unlimited number of transformersin parallel

Minimizing circulating current - Requires extra configuration efforts since thisprinciple utilizes a horizontal communicationbetween the regulators (the inputs TRx_Iconnected from parallel transformer controller'soutputs TR0_I.+ The step voltages and short circuitimpedances of the transformers do not need tobe identical.+ The phase angle of the load current may varywithout any impact on the regulation accuracy.+ Automatic adjustment for the number oftransformers (for an accurate calculation of linedrop compensation term)



9.5.16 SignalsTable 588: OLATCC Input signals




U_AB SIGNAL 0 Phase-to-phase voltage AB

TR1_TAP_POS INT32 0 Integer value representing tap changer position oftransformer 2



RAISE_LOCAL BOOLEAN 0=False Raise command input from configuration

LOWER_LOCAL BOOLEAN 0=False Lower command input from configuration

TAPCHG_FLLW BOOLEAN 0=False Change follower tap position (stop, lower, higher)

PARALLEL BOOLEAN 0=False Parallel or single operation

AUTO BOOLEAN 0=False Auto/Manual indication

CON_STATUS BOOLEAN 0=False Network connection status of the (own) transformer

LTC_BLOCK BOOLEAN 0=False External signal for blocking of automatic operation

TCO BOOLEAN 0=False Tap changer operating input

RSV BOOLEAN 0=False Reduce set voltage active

TR1_I_AMPL FLOAT32 0.00 Received current magnitude from transformer 1

TR1_I_ANGL FLOAT32 0.00 Received current angle from transformer 1





Table 589: OLATCC Output signals

Name Type DescriptionRAISE_OWN BOOLEAN Raise command for own transformer

LOWER_OWN BOOLEAN Lower command for own transformer

FLLW1_CTL INT32 Lower/Raise command for follower transformer 1in the Master/Follower operation mode



ALARM BOOLEAN Alarm status

PAR_FAIL BOOLEAN Parallel failure detected




Name Type DescriptionPARALLEL BOOLEAN Parallel or single operation

AUTO BOOLEAN Auto/Manual indication

TIMER_ON BOOLEAN Timer on

BLKD_I_LOD BOOLEAN Indication of over current blocking

BLKD_U_UN BOOLEAN Indication of under voltage blocking

RNBK_U_OV BOOLEAN Indication of raise voltage runback

BLKD_I_CIR BOOLEAN Indication of high circulating current blocking

BLKD_LTCBLK BOOLEAN Indication of external blocking

9.5.17 SettingsTable 590: OLATCC Group settings

Parameter Values (Range) Unit Step Default DescriptionAuto parallel mode 2=Auto master

3=Auto follower5=NRP7=MCC

2=Auto master Parallel mode selection

Band center voltage 0.000...2.000 xUn 0.001 1.000 Band center voltage Us

Line drop V Ris 0.0...25.0 % 0.1 0.0 Resistive line-drop compensation factor

Line drop V React 0.0...25.0 % 0.1 0.0 Reactive line-drop compensation factor

Band reduction 0.00...9.00 %Un 0.01 0.00 Step size for reduce set voltage (RSV)

Stability factor 0.0...70.0 % 0.1 0.0 Stability factor in parallel operation

Load phase angle -89...89 deg 1 0 Load phase-shift, used only with thenegative reactance principle

Control delay time 1 1000...300000 ms 100 60000 Control delay time for the first controlpulse

Control delay time 2 1000...300000 ms 100 30000 Control delay time for the followingcontrol pulses

Table 591: OLATCC Non group settings



Operation mode 1=Manual2=Auto single3=Auto parallel4=Input control

4=Input control The operation mode

Custom Man blocking 1=Custom disabled2=OC3=UV4=OC, UV5=EXT6=OC, EXT7=UV, EXT8=OC, UV, EXT

2=OC Customized manual blocking




Parameter Values (Range) Unit Step Default DescriptionParallel trafos 0...10 0 Number of parallel transformers in

addition to own transformer

Delay characteristic 0=Inverse time1=Definite time

1=Definite time Selection of delay characteristic

Band width voltage 1.20...18.00 %Un 0.01 3.00 Allowed deviation of the control voltage

Load current limit 0.10...5.00 xIn 0.01 2.00 Load current blocking limit

Block lower voltage 0.10...1.20 xUn 0.01 0.70 Voltage limit, where further voltagelowering commands are blocked

Runback raise V 0.80...2.40 xUn 0.01 1.25 Voltage limit, where fast lowercommands takes place

Cir current limit 0.10...5.00 xIn 0.01 0.15 Blocking limit for high circulating current

LDC limit 0.00...2.00 xUn 0.01 0.10 Maximum limit for line dropcompensation term

Lower block tap -36...36 0 Tap changer limit position which giveslowest voltage on the regulated side

Raise block tap -36...36 17 Tap changer limit position which giveshighest voltage on the regulated side

Max operations in 1h 0...10000 100 Allowed number of controls per one hoursliding window

Cmd error delay time 10...50 s 20 Time delay before command error will beactivated

Follower delay time 6...20 s 6 Time delay between successive followercommands by a master

LTC pulse time 500...10000 ms 100 1500 Output pulse duration, common for raiseand lower pulses

LDC enable 0=False1=True

1=True Selection for line drop compensation

Alarms enabled 0=False1=True

1=True Alarm selection

Rv Pwr flow allowed 0=False1=True

0=False Reverse power flow allowed

9.5.18 Monitored dataTable 592: OLATCC Monitored data

Name Type Values (Range) Unit DescriptionTAP_POS INT8 -36...36 Integer value

representing tap changerposition of owntransformer

TR0_I_AMPL FLOAT32 0.00...15000.00 A Transmitted currentmagnitude

TR0_I_ANGL FLOAT32 -180.00...180.00 deg Transmitted currentangle

U_MEAS FLOAT32 0.00...5.00 xUn Phase-to-phase voltage,average filtered




Name Type Values (Range) Unit DescriptionANGL_UA_IA FLOAT32 -180...180 deg Measured angle value

between phase Avoltage and current

TIMER_STS Enum 0=Timer off1=Lower timer1on2=Raise timer1on3=Lower timer2on4=Raise timer2on5=Fast lower Ton

Timer T1, T2 or fastlower timer active

OPR_MODE_STS Enum 0=Not in use1=Manual2=Auto single3=Auto master4=Auto follower5=MCC6=NRP

The acting operationmode of the functionblock

U_CTL FLOAT32 0.000...3.000 xUn Control voltage, Up,target voltage level

UD_CTL FLOAT32 -2.000...2.000 xUn Voltage differencebetween Measuredvoltage - ControlVoltage: Um - Up

I_CIR FLOAT32 -10.00...10.00 xIn Calculated circulatingcurrent - calculated inoperation modes NRPand MCC

LDC FLOAT32 -2.00...2.00 xUn Calculated line dropcompensation

BLK_STATUS INT32 0...127 Bit-coded outputshowing the blockingstatus for the nextoperation

ALARM_REAS Enum 0=No alarm1=Cmd error2=TCO error3=Cmd + TCOerr4=Pump error5=Pump + cmderr6=Pump + TCOerr7=Pmp+TCO+cmd err

Status and reason foralarm

OP_TM_NUM_H INT32 0...2147483647 Number of controls forown tap changer duringlast hour




Name Type Values (Range) Unit DescriptionFAIL_FLLW Enum 0=No failed

followers1=Follower 12=Follower 23=Followers 1+24=Follower 35=Followers 1+36=Followers 2+37=Followers1+2+3

Failed followers

PAR_UNIT_MCC Enum 0=No parall units1=Trafo 12=Trafo 23=Trafos 1 and 24=Trafo 35=Trafos 1 and 36=Trafos 2 and 37=Trafos 1+2+3

Parallel units included inMCC calculation

OPR_CNT INT32 0...2147483647 Total number of raiseand lower commandsgiven in the manual andautomatic modes

OLATCC Enum 1=on2=blocked3=test4=test/blocked5=off

Status

9.5.19 Technical dataTable 593: OLATCC Technical data

Characteristic ValueOperation accuracy1) Depending on the frequency of the current

measured: fn ±2 Hz

Differential voltage Ud = ± 0.5% of the measuredvalue or ± 0.005 x Un (in measured voltages <2.0 x Un)Operation value = ± 1.5% of the Ud for Us = 1.0x Un

Operate time accuracy in definite time mode2) + 4.0% / - 0% of the set value

Operate time accuracy in inverse time mode2) + 8.5% / - 0% of the set value(at theoretical B in range of 1.1…5.0)Also note fixed minimum operate time (IDMT) 1 s.

Reset ratio for control operationReset ratio for analogue based blockings (exceptrun back raise voltage blocking)

Typical 0.80 (1.20)Typical 0.96 (1.04)

1) Default setting values used2) Voltage before deviation = set Band center voltage.



9.5.20 Technical revision historyTable 594: OLATTC Technical revision history

Technicalrevision

Change

B Added new output TIMER_ON (new 61850 data for that). ACT interface changes byinterchanging already existing data between monitored data and output interface.Operation mode default to be changed to 4=Input control (previously it was Manual).



Section 10 Power quality measurement functions

10.1 Current total demand distortion monitoring CMHAI




Current total demand distortionmonitoring

CMHAI PQM3I PQM3I


GUID-62495CAB-20DF-4BBA-9D5C-ECDE1D2AAB52 V1 EN


10.1.3 FunctionalityThe distortion monitoring function CMHAI is used for monitoring the current totaldemand distortion TDD.


The operation of the current distortion monitoring function can be described with amodule diagram. All the modules in the diagram are explained in the next sections.

1MRS756887 G Section 10Power quality measurement functions


BLOCK

ALARMDistortion measure-

ment

I_A

I_B

I_C

Demand calculation

GUID-E5EC5FFE-7679-445B-B327-A8B1759D90C4 V1 EN


Distortion measurementThe distortion measurement module measures harmonics up to the 11th harmonic.The total demand distortion TDD is calculated from the measured harmoniccomponents with the formula

TDD

I

I

kk

N

demand

==∑

2

2

max_

GUID-9F532219-6991-4F61-8DB6-0D6A0AA9AC29 V1 EN (Equation 85)

Ik kth harmonic component

Imax_demand The maximum demand current measured by CMMXU

If CMMXU is not available in the configuration or the measured maximumdemand current is less than the Initial Dmd current setting, Initial Dmd current isused for Imax_demand.

Demand calculationThe demand value for TDD is calculated separately for each phase. If any of thecalculated total demand distortion values is above the set alarm limit TDD alarmlimit, the ALARM output is activated.

The demand calculation window is set with the Demand interval setting. It hasseven window lengths from "1 minute" to "180 minutes". The window type can beset with the Demand window setting. The available options are "Sliding" and "Non-sliding".

The activation of the BLOCK input blocks the ALARM output.

10.1.5 ApplicationIn standards, the power quality is defined through the characteristics of the supplyvoltage. Transients, short-duration and long-duration voltage variations, unbalanceand waveform distortions are the key characteristics describing power quality.Power quality is, however, a customer-driven issue. It could be said that any power

Section 10 1MRS756887 GPower quality measurement functions


problem concerning voltage or current that results in a failure or misoperation ofcustomer equipment is a power quality problem.

Harmonic distortion in a power system is caused by nonlinear devices. Electronicpower converter loads constitute the most important class of nonlinear loads in apower system. The switch mode power supplies in a number of single-phaseelectronic equipment, such as personal computers, printers and copiers, have a veryhigh third-harmonic content in the current. Three-phase electronic powerconverters, that is, dc/ac drives, however, do not generate third-harmonic currents.Still, they can be significant sources of harmonics.

Power quality monitoring is an essential service that utilities can provide for theirindustrial and key customers. Not only can a monitoring system provideinformation about system disturbances and their possible causes, it can also detectproblem conditions throughout the system before they cause customer complaints,equipment malfunctions and even equipment damage or failure. Power qualityproblems are not limited to the utility side of the system. In fact, the majority ofpower quality problems are localized within customer facilities. Thus, powerquality monitoring is not only an effective customer service strategy but also a wayto protect a utility's reputation for quality power and service.

CMHAI provides a method for monitoring the power quality by means of thecurrent waveform distortion. CMHAI provides a short-term 3-second average and along-term demand for TDD.

10.1.6 SignalsTable 595: CMHAI Input signals

Name Type Default DescriptionI_A Signal 0 Phase A current

I_B Signal 0 Phase B current

I_C Signal 0 Phase C current


Table 596: CMHAI Output signals

Name Type DescriptionALARM BOOLEAN Alarm signal for TDD



10.1.7 SettingsTable 597: CMHAI Non group settings



Demand interval 0=1 minute1=5 minutes2=10 minutes3=15 minutes4=30 minutes5=60 minutes6=180 minutes

2=10 minutes Time interval for demand calculation

Demand window 1=Sliding2=Non-sliding

1=Sliding Demand calculation window type

TDD alarm limit 1.0...100.0 % 0.1 50.0 TDD alarm limit

Initial Dmd current 0.10...1.00 xIn 0.01 1.00 Initial demand current

10.1.8 Monitored dataTable 598: CMHAI Monitored data

Name Type Values (Range) Unit DescriptionMax demand TDDIL1

FLOAT32 0.00...500.00 % Maximum demand TDDfor phase A

Max demand TDDIL2

FLOAT32 0.00...500.00 % Maximum demand TDDfor phase B

Max demand TDDIL3

FLOAT32 0.00...500.00 % Maximum demand TDDfor phase C

Time max dmd TDDIL1

Timestamp Time of maximumdemand TDD phase A

Time max dmd TDDIL2

Timestamp Time of maximumdemand TDD phase B

Time max dmd TDDIL3

Timestamp Time of maximumdemand TDD phase C

3SMHTDD_A FLOAT32 0.00...500.00 % 3 second mean value ofTDD for phase A

DMD_TDD_A FLOAT32 0.00...500.00 % Demand value for TDDfor phase A

3SMHTDD_B FLOAT32 0.00...500.00 % 3 second mean value ofTDD for phase B

DMD_TDD_B FLOAT32 0.00...500.00 % Demand value for TDDfor phase B

3SMHTDD_C FLOAT32 0.00...500.00 % 3 second mean value ofTDD for phase C

DMD_TDD_C FLOAT32 0.00...500.00 % Demand value for TDDfor phase C



10.2 Voltage total harmonic distortion monitoring VMHAI




Voltage total harmonic distortionmonitoring

VMHAI PQM3U PQM3V


GUID-CF203BDC-8C9A-442C-8D31-1AD55110469C V1 EN


10.2.3 FunctionalityThe distortion monitoring function VMHAI is used for monitoring the voltage totalharmonic distortion THD.


The operation of the voltage distortion monitoring function can be described with amodule diagram. All the modules in the diagram are explained in the next sections.

Distortion measure-

ment

Demand calculation

BLOCK

ALARM

U_A_AB

U_B_BC

U_C_CA

GUID-615D1A8A-621A-4AFA-ABB0-C681208AE62C V1 EN




Distortion measurementThe distortion measurement module measures harmonics up to the 11th harmonic.The total harmonic distortion THD for voltage is calculated from the measuredharmonic components with the formula

THD

U

U

kk

N

==∑

2

2

1

GUID-83A22E8C-5F4D-4332-A832-4E48B35550EF V1 EN (Equation 86)

Uk kth harmonic component

U1 the voltage fundamental component amplitude

Demand calculationThe demand value for THD is calculated separately for each phase. If any of thecalculated demand THD values is above the set alarm limit THD alarm limit, theALARM output is activated.

The demand calculation window is set with the Demand interval setting. It hasseven window lengths from "1 minute" to "180 minutes". The window type can beset with the Demand window setting. The available options are "Sliding" and "Non-sliding".

The activation of the BLOCK input blocks the ALARM output.

10.2.5 ApplicationVMHAI provides a method for monitoring the power quality by means of thevoltage waveform distortion. VMHAI provides a short-term three-second averageand long-term demand for THD.

10.2.6 SignalsTable 599: VMHAI Input signals

Name Type Default DescriptionU_A_AB SIGNAL 0 Phase-to-earth voltage A or phase-to-phase

voltage AB

U_B_BC SIGNAL 0 Phase-to-earth voltage B or phase-to-phasevoltage BC

U_C_CA SIGNAL 0 Phase-to-earth voltage C or phase-to-phasevoltage CA




Table 600: VMHAI Output signals

Name Type DescriptionALARM BOOLEAN Alarm signal for THD

10.2.7 SettingsTable 601: VMHAI Non group settings



Demand interval 0=1 minute1=5 minutes2=10 minutes3=15 minutes4=30 minutes5=60 minutes6=180 minutes

2=10 minutes Time interval for demand calculation

Demand window 1=Sliding2=Non-sliding

1=Sliding Demand calculation window type

THD alarm limit 1.0...100.0 % 0.1 50.0 THD alarm limit

10.2.8 Monitored dataTable 602: VMHAI Monitored data

Name Type Values (Range) Unit DescriptionMax demand THDUL1

FLOAT32 0.00...500.00 % Maximum demand THDfor phase A

Max demand THDUL2

FLOAT32 0.00...500.00 % Maximum demand THDfor phase B

Max demand THDUL3

FLOAT32 0.00...500.00 % Maximum demand THDfor phase C

Time max dmd THDUL1

Timestamp Time of maximumdemand THD phase A

Time max dmd THDUL2

Timestamp Time of maximumdemand THD phase B

Time max dmd THDUL3

Timestamp Time of maximumdemand THD phase C

3SMHTHD_A FLOAT32 0.00...500.00 % 3 second mean value ofTHD for phase A

DMD_THD_A FLOAT32 0.00...500.00 % Demand value for THDfor phase A

3SMHTHD_B FLOAT32 0.00...500.00 % 3 second mean value ofTHD for phase B




Name Type Values (Range) Unit DescriptionDMD_THD_B FLOAT32 0.00...500.00 % Demand value for THD

for phase B

3SMHTHD_C FLOAT32 0.00...500.00 % 3 second mean value ofTHD for phase C

DMD_THD_C FLOAT32 0.00...500.00 % Demand value for THDfor phase C

10.3 Voltage variation PHQVVR




Voltage variation detection function PHQVVR PQMU PQMV


GUID-9AA7CE99-C11C-4312-89B4-1C015476A165 V1 EN


10.3.3 FunctionalityThe voltage variation measurement function PHQVVR is used for measuring theshort-duration voltage variations in distribution networks.

Power quality in the voltage waveform is evaluated by measuring voltage swells,dips and interruptions. PHQVVR includes single-phase and three-phase voltagevariation modes.

Typically, short-duration voltage variations are defined to last more than half of thenominal frequency period and less than one minute. The maximum magnitude (inthe case of a voltage swell) or depth (in the case of a voltage dip or interruption)and the duration of the variation can be obtained by measuring the RMS value ofthe voltage for each phase. International standard 61000-4-30 defines the voltagevariation to be implemented using the RMS value of the voltage. IEEE standard1159-1995 provides recommendations for monitoring the electric power quality ofthe single-phase and polyphase ac power systems.



PHQVVR contains a blocking functionality. It is possible to block a set of functionoutputs or the function itself, if desired.


The operation of the voltage variation detection function can be described with amodule diagram. All the modules in the diagram are explained in the next sections.

U_A

U_BU_CI_A

I_B

I_C

GUID-91ED3E3D-F014-49EE-B4B0-DAD2509DD013 V1 EN


10.3.4.1 Phase mode setting

PHQVVR is designed for both single-phase and polyphase ac power systems, andselection can be made with the Phase mode setting, which can be set either to the"Single Phase" or "Three Phase" mode. The default setting is "Single Phase".

The basic difference between these alternatives depends on how many phases areneeded to have the voltage variation activated. When the Phase mode setting is"Single Phase", the activation is straightforward. There is no dependence betweenthe phases for variation start. The START output and the corresponding phase startare activated when the limit is exceeded or undershot. The corresponding phasestart deactivation takes place when the limit (includes small hysteresis) isundershot or exceeded. The START output is deactivated when there are no moreactive phases.

However, when Phase mode is "Three Phase", all the monitored phase signalmagnitudes, defined with Phase supervision, have to fall below or rise above thelimit setting to activate the START output and the corresponding phase output, that



is, all the monitored phases have to be activated. Accordingly, the deactivationoccurs when the activation requirement is not fulfilled, that is, one or moremonitored phase signal magnitudes return beyond their limits. Phases do not needto be activated by the same variation type to activate the START output. Anotherconsequence is that if only one or two phases are monitored, it is sufficient thatthese monitored phases activate the START output.

10.3.4.2 Variation detection

The module compares the measured voltage against the limit settings. If there is apermanent undervoltage or overvoltage, the Reference voltage setting can be set tothis voltage level to avoid the undesired voltage dip or swell indications. This isaccomplished by converting the variation limits with the Reference voltage settingin the variation detection module, that is, when there is a voltage different from thenominal voltage, the Reference voltage setting is set to this voltage.

The Variation enable setting is used for enabling or disabling the variation types.By default, the setting value is "Swell+dip+Int" and all the alternative variationtypes are indicated. For example, for setting "Swell+dip", the interruption detectionis not active and only swell or dip events are indicated.

In a case where Phase mode is "Single Phase" and the dip functionality isavailable, the output DIPST is activated when the measured TRMS value dropsbelow the Voltage dip set 3 setting in one phase and also remains above theVoltage Int set setting. If the voltage drops below the Voltage Int set setting, theoutput INTST is activated. INTST is deactivated when the voltage value risesabove the setting Voltage Int set. When the same measured TRMS magnitude risesabove the setting Voltage swell set 3, the SWELLST output is activated.

There are three setting value limits for dip (Voltage dip set 1..3) and swellactivation (Voltage swell set 1..3) and one setting value limit for interruption.

If Phase mode is "Three Phase", the DIPST and INTST outputs areactivated when the voltage levels of all monitored phases, definedwith the parameter Phase supervision, drop below the Voltage Intset setting value. An example for the detection principle of voltageinterruption for "Three Phase" when Phase supervision is "Ph A +B + C", and also the corresponding start signals when Phase modeis "Single Phase", are as shown in the example for the detection of athree-phase interruption.



U_A

U_C U_B

DIPST

INTST

SWELLST

Voltage Int set

Voltage dip set

Voltage swell set

FALSETRUE FALSETRUE

FALSETRUE

DIPST

INTST

SWELLST

FALSETRUE FALSETRUE

FALSETRUE

A) Three phase mode

B) Single phase modeGUID-F44C8E6E-9354-44E4-9B2E-600D66B76C1A V1 EN

Figure 379: Detection of three-phase voltage interruption

The module measures voltage variation magnitude on each phase separately, thatis, there are phase-segregated outputs ST_A, ST_B and ST_C for voltage variationindication. The configuration parameter Phase supervision defines which voltagephase or phases are monitored. If a voltage phase is selected to be monitored, thefunction assumes it to be connected to a voltage measurement channel. In otherwords, if an unconnected phase is monitored, the function falsely detects a voltageinterruption in that phase.

The maximum magnitude and depth are defined as percentage values calculatedfrom the difference between the reference and the measured voltage. For example,a dip to 70 percent means that the minimum voltage dip magnitude variation is 70percent of the reference voltage amplitude.

The activation of the BLOCK input resets the function and outputs.

10.3.4.3 Variation validation

The validation criterion for voltage variation is that the measured total variationduration is between the set minimum and maximum durations (Either one of VVadip time 1, VVa swell time 1 or VVa Int time 1, depending on the variation type, andVVa Dur Max). The maximum variation duration setting is the same for allvariation types.



Figure 380 shows voltage dip operational regions. In Figure 379, only one voltagedip/swell/Int set is drawn, whereas in this figure there are three sub-limits for thedip operation. When Voltage dip set 3 is undershot, the corresponding ST_x andalso the DIPST outputs are activated. When the TRMS voltage magnitude remainsbetween Voltage dip set 2 and Voltage dip set 1 for a period longer than VVa diptime 2 (shorter time than VVa dip time 3), a momentary dip event is detected.Furthermore, if the signal magnitude stays between the limits longer than VVa diptime 3 (shorter time than VVa Dur max), a temporary dip event is detected. If thevoltage remains below Voltage dip set 1 for a period longer than VVa dip time 1 buta shorter time than VVa dip time 2, an instantaneous dip event is detected.

For an event detection, the OPERATE output is always activated for one task cycle.The corresponding counter and only one of them (INSTDIPCNT, MOMDIPCNTor TEMPDIPCNT) is increased by one. If the dip limit undershooting duration isshorter than VVa dip time 1, VVa swell time 1 or VVa Int time 1, the event is notdetected at all, and if the duration is longer than VVa Dur Max,MAXDURDIPCNT is increased by one but no event detection resulting in theactivation of the OPERATE output and recording data update takes place. Thesecounters are available through the monitored data view on the LHMI or throughtools via communications. There are no phase-segregated counters but all thevariation detections are registered to a common time/magnitude-classified countertype. Consequently, a simultaneous multiphase event, that is, the variation-typeevent detection time moment is exactly the same for two or more phases, iscounted only once also for single-phase power systems.

Voltage dip set 1

Voltage dip set 2

Voltage dip set 3

VoltagexUref

Time (ms)0

0VVa Dur MaxVVa dip time 3VVa dip time 1 VVa dip time 2

1.00

Instantaneousdip

TemporarydipMomentary

dip

Maximum durationdip

GUID-0D3F6D81-F905-4D8D-A579-836EF7BB6773 V1 EN

Figure 380: Voltage dip operational regions

In Figure 381, the corresponding limits regarding the swell operation are providedwith the inherent magnitude limit order difference. The swell functionalityprinciple is the same as for dips, but the different limits for the signal magnitudeand times and the inherent operating zone change (here, Voltage swell set x > 1.0xUn) are applied.



Voltage swell set 3

Voltage swell set 2

Voltage swell set 1

VoltagexUref

Time (ms)0

0VVa Dur MaxVVa swell time 3VVa swell time 1 VVa swell time 2

1.40Instantaneous

swellTemporary

swell

Momentaryswell Maximum duration

swell

1.00

GUID-7F23358A-5B42-4F5B-8F12-B157208C8945 V1 EN

Figure 381: Voltage swell operational regions

For interruption, as shown in Figure 382, there is only one magnitude limit but fourduration limits for interruption classification. Now the event and counter typedepends only on variation duration time.

Voltage Int set

VoltagexUref

Time (ms)0

0VVa Dur MaxVVa Int time 3VVa Int time 1 VVa Int time 2

1.00

Momentaryinterruption

Sustainedinterruption

Temporaryinterruption

Maximum durationinterruption

GUID-AA022CA2-4CBF-49A1-B710-AB602F8C8343 V1 EN

Figure 382: Interruption operating regions

Generally, no event detection is done if both the magnitude and durationrequirements are not fulfilled. For example, the dip event does not indicate if theTRMS voltage magnitude remains between Voltage dip set 3 and Voltage dip set 2for a period shorter than VVa dip time 3 before rising back above Voltage dip set 3.

The event indication ends and possible detection is done when the TRMS voltagereturns above (for dip and interruption) or below (for swell) the activation-startinglimit. For example, after an instantaneous dip, the event indication when thevoltage magnitude exceeds Voltage dip set 1 is not detected (and recorded)immediately but only if no longer dip indication for the same dip variation takesplace and maximum duration time for dip variation does not exceed before thesignal magnitude rises above Voltage dip set 3. There is a small hysteresis for allthese limits to avoid the oscillation of the output activation. No drop-off approachis applied here due to the hysteresis.



Consequently, only one event detection and recording of the same variation typecan take place for one voltage variation, so the longest indicated variation of eachvariation type is detected. Furthermore, it is possible that another instantaneous dipevent replaces the one already indicated if the magnitude again undershootsVoltage dip set 1 for the set time after the first detection and the signal magnitudeor time requirement is again fulfilled. Another possibility is that if the timecondition is not fulfilled for an instantaneous dip detection but the signal risesabove Voltage dip set 1, the already elapsed time is included in the momentary diptimer. Especially the interruption time is included in the dip time. If the signal doesnot exceed Voltage dip set 2 before the timer VVa dip time 2 has elapsed when themomentary dip timer is also started after the magnitude undershooting Voltage dipset 2, the momentary dip event instead is detected. Consequently, the same dipoccurrence with a changing variation depth can result in several dip eventindications but only one detection. For example, if the magnitude has undershotVoltage dip set 1 but remained above Voltage Intr set for a shorter time than thevalue of VVa dip time 1 but the signal rises between Voltage dip set 1 and Voltagedip set 2 so that the total duration of the dip activation is longer than VVa dip time2 and the maximum time is not overshot, this is detected as a momentary dip eventhough a short instantaneous dip period has been included. In text, the terms"deeper" and "higher" are used for referring to dip or interruption.

Although examples are given for dip events, the same rules can be applied to theswell and interruption functionality too. For swell indication, "deeper" means thatthe signal rises even more and "higher" means that the signal magnitude becomeslower respectively.

The adjustable voltage thresholds adhere to the relationships:

VVa dip time 1 ≤ VVa dip time 2 ≤ VVa dip time 3.

VVa swell time 1 ≤ VVa swell time 2 ≤ VVa swell time 3.

VVa Int time 1 ≤ VVa Int time 2 ≤ VVa Int time 3.

There is a validation functionality built-in function that checks the relationshipadherence so that if VVa x time 1 is set higher than VVa x time 2 or VVa x time 3,VVa x time 2 and VVa x time 3 are set equal to the new VVa x time 1. If VVa x time2 is set higher than VVa x time 3, VVa x time 3 is set to the new VVa x time 2. IfVVa x time 2 is set lower than VVa x time 1, the entered VVa x time 2 is rejected. IfVVa x time 3 is set lower than VVa x time 2, the entered VVa x time 3 is rejected.

10.3.4.4 Duration measurement

The duration of each voltage phase corresponds to the period during which themeasured TRMS values remain above (swell) or below (dip, interruption) thecorresponding limit.

Besides the three limit settings for the variation types dip and swell, there is also aspecific duration setting for each limit setting. For interruption, there is only one



limit setting common for the three duration settings. The maximum duration settingis common for all variation types.

The duration measurement module measures the voltage variation duration of eachphase voltage separately when the Phase mode setting is "Single Phase". The phasevariation durations are independent. However, when the Phase mode setting is"Three Phase", voltage variation may start only when all the monitored phases areactive. An example of variation duration when Phase mode is "Single Phase" canbe seen in Figure 383. The voltage variation in the example is detected as aninterruption for the phase B and a dip for the phase A, and also the variationdurations are interpreted as independent U_B and U_A durations. In case of single-phase interruption, the DIPST output is active when either ST_A or ST_B isactive. The measured variation durations are the times measured between theactivation of the ST_A or ST_B outputs and deactivation of the ST_A or ST_Boutputs. When the Phase mode setting is "Three Phase", the example case does notresult in any activation.

GUID-22014C0F-9FE2-4528-80BA-AEE2CD9813B8 V1 EN

Figure 383: Single-phase interruption for the Phase mode value "Single Phase"

10.3.4.5 Three/single-phase selection variation examples

The provided rules always apply for single-phase (Phase Mode is "Single Phase")power systems. However, for three-phase power systems (where Phase Mode is"Three Phase"), it is required that all the phases have to be activated before theactivation of the START output. Interruption event indication requires all threephases to undershoot Voltage Int set simultaneously, as shown in Figure 379. Whenthe requirement for interruption for "Three Phase" is no longer fulfilled, variationis indicated as a dip as long as all phases are active.

In case of a single-phase interruption of Figure 383, when there is a dip indicated inanother phase but the third phase is not active, there is no variation indication startwhen Phase Mode is "Three Phase". In this case, only the Phase Mode value"Single Phase" results in the ST_B interruption and the ST_A dip.



It is also possible that there are simultaneously a dip in one phase and a swell inother phases. The functionality of the corresponding event indication with oneinactive phase is shown in Figure 384. Here, the "Swell + dip" variation type ofPhase mode is "Single Phase". For the selection "Three Phase" of Phase mode, noevent indication or any activation takes place due to a non-active phase.

U_A

U_C

U_B

ST_BST_C

ST_A

DIPST

INTST

SWELLST

SWELLOPR

INTOPRDIPOPR

Voltage Int set

Voltage dip set

Voltage swell set

FALSETRUE FALSETRUE

FALSETRUE

FALSETRUE FALSETRUE

FALSETRUE

FALSETRUE FALSETRUE

FALSETRUE

GUID-0657A163-7D42-4543-8EC8-3DF84E2F0BF5 V1 EN

Figure 384: Concurrent dip and swell when Phase mode is "Single Phase"

In Figure 385, one phase is in dip and two phases have a swell indication. For thePhase Mode value "Three Phase", the activation occurs only when all the phasesare active. Furthermore, both swell and dip variation event detections take placesimultaneously. In case of a concurrent voltage dip and voltage swell, bothSWELLCNT and DIPCNT are incremented by one.

Also Figure 385 shows that for the Phase Mode value "Three Phase", two differenttime moment variation event swell detections take place and, consequently,DIPCNT is incremented by one but SWELLCNT is totally incremented by two.Both in Figure 384 and Figure 385 it is assumed that variation durations aresufficient for detections to take place.



U_A

U_C

U_B

ST_BST_C

ST_A

DIPST

INTST

SWELLST

SWELLOPR

INTOPRDIPOPR

Voltage Int set

Voltage dip set

Voltage swell set

FALSETRUE FALSETRUE

FALSETRUE

FALSETRUE FALSETRUE

FALSETRUE

FALSETRUE FALSETRUE

FALSETRUE

ST_BST_C

ST_A

DIPST

INTST

SWELLST

SWELLOPR

INTOPRDIPOPR

FALSETRUE FALSETRUE

FALSETRUE

FALSETRUE FALSETRUE

FALSETRUE

FALSETRUE FALSETRUE

FALSETRUE

A) Three phase mode

B) Single phase modeGUID-1C0C906B-EC91-4C59-9291-B5002830E590 V1 EN

Figure 385: Concurrent dip and two-phase swell

10.3.5 Recorded dataBesides counter increments, the information required for a later fault analysis isstored after a valid voltage variation is detected.

Recorded data informationWhen voltage variation starts, the phase current magnitudes preceding theactivation moment are stored. Also, the initial voltage magnitudes are temporarilystored at the variation starting moment. If the variation is, for example, a two-phasevoltage dip, the voltage magnitude of the non-active phase is stored from this samemoment, as shown in Figure 386. The function tracks each variation-active voltage



phase, and the minimum or maximum magnitude corresponding to swell or dip/interruption during variation is temporarily stored. If the minimum or maximum isfound in tracking and a new magnitude is stored, also the inactive phase voltagesare stored at the same moment, that is, the inactive phases are not magnitude-tracked. The time instant (time stamp) at which the minimum or maximummagnitude is measured is also temporarily stored for each voltage phase wherevariation is active. Finally, variation detection triggers the recorded data updatewhen the variation activation ends and the maximum duration time is not exceeded.

The data objects to be recorded for PHQVVR are given in Table 603. There aretotally three data banks, and the information given in the table refers to one databank content.

The three sets of recorded data available are saved in data banks 1-3. The data bank1 holds always the most recent recorded data, and the older data sets are moved tothe next banks (1→2 and 2→3) when a valid voltage variation is detected. Whenall three banks have data and a new variation is detected, the newest data are placedinto bank 1 and the data in bank 3 are overwritten by the data from bank 2.

Figure 386 shows a valid recorded voltage interruption and two dips for the Phasemode value "Single Phase". The first dip event duration is based on the U_Aduration, while the second dip is based on the time difference between the dip stopand start times. The first detected event is an interruption based on the U_Bduration given in Figure 386. It is shown also with dotted arrows how voltage timestamps are taken before the final time stamp for recording, which is shown as asolid arrow. Here, the U_B timestamp is not taken when the U_A activation starts.

U_A

U_C

U_BU_A duration

U_B duration

U_B amplitude & timestamp

U_A amplitude & timestamp

U_C amplitude & timestamp

Voltage dip set

Voltage swell set

Dip

star

t

Dip

stop

Voltage Int set

GUID-7A859344-8960-4CF3-B637-E2DE6D3BDA85 V1 EN

Figure 386: Valid recorded voltage interruption and two dips



Table 603: PHQVVR recording data bank parameters

Parameter description Parameter nameEvent detection triggering time stamp Time

Variation type Variation type

Variation magnitude Ph A Variation Ph A

Variation magnitude Ph A time stamp (maximum/minimum magnitude measuring time momentduring variation)

Var Ph A rec time

Variation magnitude Ph B Variation Ph B

Variation magnitude Ph B time stamp (maximum/minimum magnitude measuring time momentduring variation)

Var Ph B rec time

Variation magnitude Ph C Variation Ph C

Variation magnitude Ph C time stamp (maximum/minimum magnitude measuring time momentduring variation)

Var Ph C rec time

Variation duration Ph A Variation Dur Ph A

Variation Ph A start time stamp (phase Avariation start time moment)

Var Dur Ph A time

Variation duration Ph B Variation Dur Ph B

Variation Ph B start time stamp (phase Bvariation start time moment)

Var Dur Ph B time

Variation duration Ph C Variation Dur Ph C

Variation Ph C start time stamp (phase Cvariation start time moment)

Var Dur Ph C time

Current magnitude Ph A preceding variation Var current Ph A

Current magnitude Ph B preceding variation Var current Ph B

Current magnitude Ph C preceding variation Var current Ph C

Table 604: Enumeration values for the recorded data parameters

Setting name Enum name ValueVariation type Swell 1

Variation type Dip 2

Variation type Swell + dip 3

Variation type Interruption 4

Variation type Swell + Int 5

Variation type Dip + Int 6

Variation type Swell+dip+Int 7

10.3.6 ApplicationVoltage variations are the most typical power quality variations on the publicelectric network. Typically, short-duration voltage variations are defined to last



more than half of the nominal frequency period and less than one minute(European Standard EN 50160 and IEEE Std 1159-1995).

These short-duration voltage variations are almost always caused by a faultcondition. Depending on where the fault is located, it can cause either a temporaryvoltage rise (swell) or voltage drop (dip). A special case of voltage drop is thecomplete loss of voltage (interruption).

PHQVVR is used for measuring short-duration voltage variations in distributionnetworks. The power quality is evaluated in the voltage waveform by measuringthe voltage swells, dips and interruptions.

U_B

interruption

dip

swell

duration

max duration

magnitude

Voltage Int set

Voltage dip set

Voltage swell set

V Var Dur point 1 V Var Dur point 2

min duration

GUID-EF7957CE-E6EF-483E-A879-ABD003AC1AF9 V1 EN

Figure 387: Duration and voltage magnitude limits for swell, dip andinterruption measurement

Voltage dips disturb the sensitive equipment such as computers connected to thepower system and may result in the failure of the equipment. Voltage dips aretypically caused by faults occurring in the power distribution system. Typicalreasons for the faults are lightning strikes and tree contacts. In addition to faultsituations, the switching of heavy loads and starting of large motors also cause dips.

Voltage swells cause extra stress for the network components and the devicesconnected to the power system. Voltage swells are typically caused by the earthfaults that occur in the power distribution system.

Voltage interruptions are typically associated with the switchgear operation relatedto the occurrence and termination of short circuits. The operation of a circuitbreaker disconnects a part of the system from the source of energy. In the case ofoverhead networks, automatic reclosing sequences are often applied to the circuit



breakers that interrupt fault currents. All these actions result in a sudden reductionof voltages on all voltage phases.

Due to the nature of voltage variations, the power quality standards do not specifyany acceptance limits. There are only indicative values for, for example, voltagedips in the European standard EN 50160. However, the power quality standardslike the international standard IEC 61000-4-30 specify that the voltage variationevent is characterized by its duration and magnitude. Furthermore, IEEE Std1159-1995 gives the recommended practice for monitoring the electric power quality.

Voltage variation measurement can be done to the phase-to-earth and phase-to-phase voltages. The power quality standards do not specify whether themeasurement should be done to phase or phase-to-phase voltages. However, insome cases it is preferable to use phase-to-earth voltages for measurement. Themeasurement mode is always TRMS.

10.3.7 SignalsTable 605: PHQVVR Input signals

Name Type Default DescriptionI_A SIGNAL 0 Phase A current magnitude

I_B SIGNAL 0 Phase B current magnitude

I_C SIGNAL 0 Phase C current magnitude

U_A SIGNAL 0 Phase-to-earth voltage A

U_B SIGNAL 0 Phase-to-earth voltage B

U_C SIGNAL 0 Phase-to-earth voltage C


Table 606: PHQVVR Output signals

Name Type DescriptionOPERATE BOOLEAN Voltage variation detected

START BOOLEAN Voltage variation present

SWELLST BOOLEAN Voltage swell active

DIPST BOOLEAN Voltage dip active

INTST BOOLEAN Voltage interruption active



10.3.8 SettingsTable 607: PHQVVR Group settings

Parameter Values (Range) Unit Step Default DescriptionReference voltage 10.0...200.0 %Un 0.1 57.7 Reference supply voltage in %

Voltage dip set 1 10.0...100.0 % 0.1 80.0 Dip limit 1 in % of reference voltage

VVa dip time 1 0.5...54.0 cycles 0.1 3.0 Voltage variation dip duration 1


VVa dip time 2 10.0...180.0 cycles 0.1 30.0 Voltage variation dip duration 2


VVa dip time 3 2000...60000 ms 10 3000 Voltage variation dip duration 3

Voltage swell set 1 100.0...140.0 % 0.1 120.0 Swell limit 1 in % of reference voltage

VVa swell time 1 0.5...54.0 cycles 0.1 0.5 Voltage variation swell duration 1


VVa swell time 2 10.0...80.0 cycles 0.1 10.0 Voltage variation swell duration 2


VVa swell time 3 2000...60000 ms 10 2000 Voltage variation swell duration 3

Voltage Int set 0.0...100.0 % 0.1 10.0 Interruption limit in % of reference voltage

VVa Int time 1 0.5...30.0 cycles 0.1 3.0 Voltage variation Int duration 1

VVa Int time 2 10.0...180.0 cycles 0.1 30.0 Voltage variation Int duration 2

VVa Int time 3 2000...60000 ms 10 3000 Voltage variation interruption duration 3

VVa Dur Max 100...3600000 ms 100 60000 Maximum voltage variation duration

Table 608: PHQVVR Non group settings



Phase supervision 1=Ph A2=Ph B3=Ph A + B4=Ph C5=Ph A + C6=Ph B + C7=Ph A + B + C

7=Ph A + B + C Monitored voltage phase

Phase mode 1=Three Phase2=Single Phase

2=Single Phase Three/Single phase mode

Variation enable 1=Swell2=Dip3=Swell + dip4=Interruption5=Swell + Int6=Dip + Int7=Swell+dip+Int

7=Swell+dip+Int Enable variation type



10.3.9 Monitored dataTable 609: PHQVVR Monitored data

Name Type Values (Range) Unit DescriptionST_A BOOLEAN 0=False

1=True Start Phase A (Voltage

Variation Event inprogress)

ST_B BOOLEAN 0=False1=True

Start Phase B (VoltageVariation Event inprogress)

ST_C BOOLEAN 0=False1=True

Start Phase C (VoltageVariation Event inprogress)

INSTSWELLCNT INT32 0...2147483647 Instantaneous swelloperation counter

MOMSWELLCNT INT32 0...2147483647 Momentary swelloperation counter

TEMPSWELLCNT INT32 0...2147483647 Temporary swelloperation counter

MAXDURSWELLCNT

INT32 0...2147483647 Maximum duration swelloperation counter

INSTDIPCNT INT32 0...2147483647 Instantaneous dipoperation counter

MOMDIPCNT INT32 0...2147483647 Momentary dip operationcounter

TEMPDIPCNT INT32 0...2147483647 Temporary dip operationcounter

MAXDURDIPCNT INT32 0...2147483647 Maximum duration dipoperation counter

MOMINTCNT INT32 0...2147483647 Momentary interruptionoperation counter

TEMPINTCNT INT32 0...2147483647 Temporary interruptionoperation counter

SUSTINTCNT INT32 0...2147483647 Sustained interruptionoperation counter

MAXDURINTCNT INT32 0...2147483647 Maximum durationinterruption operationcounter

PHQVVR Enum 1=on2=blocked3=test4=test/blocked5=off

Status

Time Timestamp Time

Variation type Enum 0=No variation1=Swell2=Dip3=Swell + dip4=Interruption5=Swell + Int6=Dip + Int7=Swell+dip+Int

Variation type




Name Type Values (Range) Unit DescriptionVariation Ph A FLOAT32 0.00...5.00 xUn Variation magnitude

Phase A

Var Ph A rec time Timestamp Variation magnitudePhase A time stamp

Variation Ph B FLOAT32 0.00...5.00 xUn Variation magnitudePhase B

Var Ph B rec time Timestamp Variation magnitudePhase B time stamp

Variation Ph C FLOAT32 0.00...5.00 xUn Variation magnitudePhase C

Var Ph C rec time Timestamp Variation magnitudePhase C time stamp

Variation Dur Ph A FLOAT32 0.000...3600.000 s Variation duration PhaseA

Var Dur Ph A time Timestamp Variation Ph A start timestamp

Variation Dur Ph B FLOAT32 0.000...3600.000 s Variation duration PhaseB

Var Dur Ph B time Timestamp Variation Ph B start timestamp

Variation Dur Ph C FLOAT32 0.000...3600.000 s Variation duration PhaseC

Var Dur Ph C time Timestamp Variation Ph C start timestamp

Var current Ph A FLOAT32 0.00...60.00 xIn Current magnitudePhase A precedingvariation

Var current Ph B FLOAT32 0.00...60.00 xIn Current magnitudePhase B precedingvariation

Var current Ph C FLOAT32 0.00...60.00 xIn Current magnitudePhase C precedingvariation

Time Timestamp Time


Variation type

Variation Ph A FLOAT32 0.00...5.00 xUn Variation magnitudePhase A







Name Type Values (Range) Unit DescriptionVariation Ph C FLOAT32 0.00...5.00 xUn Variation magnitude

Phase C




Variation Dur Ph B FLOAT32 0.000...3600.000 s Variation duration PhaseB







Time Timestamp Time


Variation type

Variation Ph A FLOAT32 0.00...5.00 xUn Variation magnitudePhase A




Variation Ph C FLOAT32 0.00...5.00 xUn Variation magnitudePhase C







Name Type Values (Range) Unit DescriptionVariation Dur Ph B FLOAT32 0.000...3600.000 s Variation duration Phase

B









Section 11 General function block features

11.1 Definite time characteristics

11.1.1 Definite time operationThe DT mode is enabled when the Operating curve type setting is selected either as"ANSI Def. Time" or "IEC Def. Time". In the DT mode, the OPERATE output ofthe function is activated when the time calculation exceeds the set Operate delaytime.

The user can determine the reset in the DT mode with the Reset delay time setting,which provides the delayed reset property when needed.

The Type of reset curve setting has no effect on the reset methodwhen the DT mode is selected, but the reset is determined solelywith the Reset delay time setting.

The purpose of the delayed reset is to enable fast clearance of intermittent faults,for example self-sealing insulation faults, and severe faults which may producehigh asymmetrical fault currents that partially saturate the current transformers. Itis typical for an intermittent fault that the fault current contains so called drop-offperiods, during which the fault current falls below the set start current, includinghysteresis. Without the delayed reset function, the operate timer would reset whenthe current drops off. In the same way, an apparent drop-off period of thesecondary current of the saturated current transformer can also reset the operate timer.

1MRS756887 G Section 11General function block features


A060764 V1 EN

Figure 388: Operation of the counter in drop-off

In case 1, the reset is delayed with the Reset delay time setting and in case 2, thecounter is reset immediately, because the Reset delay time setting is set to zero.

A070421 V1 EN

Figure 389: Drop-off period is longer than the set Reset delay time

Section 11 1MRS756887 GGeneral function block features


When the drop-off period is longer than the set Reset delay time, as described inFigure 389, the input signal for the definite timer (here: timer input) is active,provided that the current is above the set Start value. The input signal is inactivewhen the current is below the set Start value and the set hysteresis region. Thetimer input rises when a fault current is detected. The definite timer activates theSTART output and the operate timer starts elapsing. The reset (drop-off) timerstarts when the timer input falls, that is, the fault disappears. When the reset (drop-off) timer elapses, the operate timer is reset. Since this happens before another startoccurs, the OPERATE output is not activated.

A070420 V1 EN

Figure 390: Drop-off period is shorter than the set Reset delay time

When the drop-off period is shorter than the set Reset delay time, as described inFigure 390, the input signal for the definite timer (here: timer input) is active,provided that the current is above the set Start value. The input signal is inactivewhen the current is below the set Start value and the set hysteresis region. Thetimer input rises when a fault current is detected. The definite timer activates theSTART output and the operate timer starts elapsing. The Reset (drop-off) timerstarts when the timer input falls, that is, the fault disappears. Another fault situationoccurs before the reset (drop-off) timer has elapsed. This causes the activation ofthe OPERATE output, since the operate timer already has elapsed.



A070422 V1 EN

Figure 391: Operating effect of the BLOCK input when the selected blockingmode is "Freeze timer"

If the BLOCK input is activated when the operate timer is running, as described inFigure 391, the timer is frozen during the time BLOCK remains active. If the timerinput is not active longer than specified by the Reset delay time setting, the operatetimer is reset in the same way as described in Figure 389, regardless of the BLOCKinput .

The selected blocking mode is "Freeze timer".

11.2 Current based inverse definite minimum timecharacteristics

11.2.1 IDMT curves for overcurrent protectionThe inverse-time modes, the operation time depends on the momentary value of thecurrent: the higher the current, the faster the operation time. The operation timecalculation or integration starts immediately when the current exceeds the set Startvalue and the START output is activated.



The OPERATE output of the component is activated when the cumulative sum ofthe integrator calculating the overcurrent situation exceeds the value set by theinverse-time mode. The set value depends on the selected curve type and thesetting values used. The curve scaling is determined with the Time multiplier setting.

There are two methods to level out the inverse-time characteristic.

• The Minimum operate time setting defines the minimum operating time for theIDMT curve, that is, the operation time is always at least the Minimum operatetime setting.

• Alternatively, the IDMT Sat point is used for giving the leveling-out point as amultiple of the Start value setting. (Global setting: Configuration/System/IDMT Sat point). The default parameter value is 50. This setting affects onlythe overcurrent and earth-fault IDMT timers.

IDMT operation time at currents over 50 x In is not guaranteed.



GUID-20353F8B-2112-41CB-8F68-B51F8ACA775E V1 EN

Figure 392: Operation time curve based on the IDMT characteristic leveled outwith the Minimum operate time setting is set to 1000 milliseconds(the IDMT Sat point setting is set to maximum).



GUID-87A96860-4268-4AD1-ABA1-3227D3BB36D5 V1 EN

Figure 393: Operation time curve based on the IDMT characteristic leveled outwith IDMT Sat point setting value “11” (the Minimum operate timesetting is set to minimum).



GUID-9BFD6DC5-08B5-4755-A899-DF5ED26E75F6 V1 EN

Figure 394: Example of how the inverse time characteristic is leveled out withcurrents over 50 x In and the Setting Start value setting “2.5 x In”.(the IDMT Sat point setting is set to maximum and the Minimumoperate time setting is set to minimum).

The grey zone in Figure 394 shows the behavior of the curve in case the measuredcurrent is outside the guaranteed measuring range. Also, the maximum measuredcurrent of 50 x In gives the leveling-out point 50/2.5 = 20 x I/I>.

11.2.1.1 Standard inverse-time characteristics

For inverse-time operation, both IEC and ANSI/IEEE standardized inverse-timecharacteristics are supported.



The operate times for the ANSI and IEC IDMT curves are defined with thecoefficients A, B and C.

The values of the coefficients can be calculated according to the formula:

t sA

I

I

B kc

[ ] =

>

−

+

⋅

1



I measured current

I> set Start value

k set Time multiplier

Table 610: Curve parameters for ANSI and IEC IDMT curves

Curve name A B C(1) ANSI ExtremelyInverse

28.2 0.1217 2.0

(2) ANSI Very Inverse 19.61 0.491 2.0

(3) ANSI NormalInverse

0.0086 0.0185 0.02

(4) ANSI ModeratelyInverse

0.0515 0.1140 0.02

(6) Long TimeExtremely Inverse

64.07 0.250 2.0

(7) Long Time VeryInverse

28.55 0.712 2.0

(8) Long Time Inverse 0.086 0.185 0.02

(9) IEC Normal Inverse 0.14 0.0 0.02

(10) IEC Very Inverse 13.5 0.0 1.0

(11) IEC Inverse 0.14 0.0 0.02

(12) IEC ExtremelyInverse

80.0 0.0 2.0

(13) IEC Short TimeInverse

0.05 0.0 0.04

(14) IEC Long TimeInverse

120 0.0 1.0



A070750 V2 EN

Figure 395: ANSI extremely inverse-time characteristics



A070751 V2 EN

Figure 396: ANSI very inverse-time characteristics



A070752 V2 EN

Figure 397: ANSI normal inverse-time characteristics



A070753 V2 EN

Figure 398: ANSI moderately inverse-time characteristics



A070817 V2 EN

Figure 399: ANSI long-time extremely inverse-time characteristics



A070818 V2 EN

Figure 400: ANSI long-time very inverse-time characteristics



A070819 V2 EN

Figure 401: ANSI long-time inverse-time characteristics



A070820 V2 EN

Figure 402: IEC normal inverse-time characteristics



A070821 V2 EN

Figure 403: IEC very inverse-time characteristics



A070822 V2 EN

Figure 404: IEC inverse-time characteristics



A070823 V2 EN

Figure 405: IEC extremely inverse-time characteristics



A070824 V2 EN

Figure 406: IEC short-time inverse-time characteristics



A070825 V2 EN

Figure 407: IEC long-time inverse-time characteristics



11.2.1.2 User-programmable inverse-time characteristics

The user can define curves by entering parameters into the following standardformula:


t[s] Operate time (in seconds)

A set Curve parameter A

B set Curve parameter B

C set Curve parameter C

E set Curve parameter E

I Measured current

I> set Start value


11.2.1.3 RI and RD-type inverse-time characteristics

The RI-type simulates the behavior of electromechanical relays. The RD-type is anearth-fault specific characteristic.

The RI-type is calculated using the formula

t sk

I

I

[ ]

. .

=

− ×>

0 339 0 236


The RD-type is calculated using the formula

t sI

k I[ ] . .= − ×

× >

5 8 1 35 In




t[s] Operate time (in seconds)


I Measured current

I> set Start value



A070826 V2 EN

Figure 408: RI-type inverse-time characteristics



A070827 V2 EN

Figure 409: RD-type inverse-time characteristics



11.2.2 Reset in inverse-time modesThe user can select the reset characteristics by using the Type of reset curve setting.

Table 611: Values for reset mode

Setting name Possible valuesType of reset curve 1=Immediate

2=Def time reset3=Inverse reset

Immediate resetIf the Type of reset curve setting in a drop-off case is selected as "Immediate", theinverse timer resets immediately.

Definite time resetThe definite type of reset in the inverse-time mode can be achieved by setting theType of reset curve parameter to “Def time reset”. As a result, the operate inverse-time counter is frozen for the time determined with the Reset delay time settingafter the current drops below the set Start value, including hysteresis.The integralsum of the inverse-time counter is reset, if another start does not occur during thereset delay.

If the Type of reset curve setting is selected as “Def time reset”, thecurrent level has no influence on the reset characteristic.

Inverse reset

Inverse reset curves are available only for ANSI and user-programmable curves. If you use other curve types, immediate resetoccurs.

Standard delayed inverse reset

The reset characteristic required in ANSI (IEEE) inverse-time modes is providedby setting the Type of reset curve parameter to “Inverse reset”. In this mode, thetime delay for reset is given with the following formula using the coefficient D,which has its values defined in the table below.

t sD

I

I

k[ ] =

>

−

⋅2

1




t[s] Reset time (in seconds)


I Measured current

I> set Start value

Table 612: Coefficients for ANSI delayed inverse reset curves

Curve name D(1) ANSI Extremely Inverse 29.1

(2) ANSI Very Inverse 21.6

(3) ANSI Normal Inverse 0.46

(4) ANSI Moderately Inverse 4.85

(6) Long Time Extremely Inverse 30

(7) Long Time Very Inverse 13.46

(8) Long Time Inverse 4.6



A070828 V1 EN

Figure 410: ANSI extremely inverse reset time characteristics



A070829 V1 EN

Figure 411: ANSI very inverse reset time characteristics



A070830 V1 EN

Figure 412: ANSI normal inverse reset time characteristics



A070831 V1 EN

Figure 413: ANSI moderately inverse reset time characteristics



A070832 V1 EN

Figure 414: ANSI long-time extremely inverse reset time characteristics



A070833 V1 EN

Figure 415: ANSI long-time very inverse reset time characteristics



A070834 V1 EN

Figure 416: ANSI long-time inverse reset time characteristics

The delayed inverse-time reset is not available for IEC-type inversetime curves.

User-programmable delayed inverse reset



The user can define the delayed inverse reset time characteristics with thefollowing formula using the set Curve parameter D.

t sD

I

I

k[ ] =

>

−

⋅2

1


t[s] Reset time (in seconds)


D set Curve parameter D

I Measured current

I> set Start value

11.2.3 Inverse-timer freezingWhen the BLOCK input is active, the internal value of the time counter is frozen atthe value of the moment just before the freezing. Freezing of the counter value ischosen when the user does not wish the counter value to count upwards or to bereset. This may be the case, for example, when the inverse-time function of an IEDneeds to be blocked to enable the definite-time operation of another IED forselectivity reasons, especially if different relaying techniques (old and modernrelays) are applied.

The selected blocking mode is "Freeze timer".

The activation of the BLOCK input also lengthens the minimumdelay value of the timer.

Activating the BLOCK input alone does not affect the operation of the STARToutput. It still becomes active when the current exceeds the set Start value, andinactive when the current falls below the set Start value and the set Reset delaytime has expired.



11.3 Voltage based inverse definite minimum timecharacteristics

11.3.1 IDMT curves for overvoltage protectionIn inverse-time modes, the operate time depends on the momentary value of thevoltage, the higher the voltage, the faster the operate time. The operate timecalculation or integration starts immediately when the voltage exceeds the set valueof the Start value setting and the START output is activated.

The OPERATE output of the component is activated when the cumulative sum ofthe integrator calculating the overvoltage situation exceeds the value set by theinverse time mode. The set value depends on the selected curve type and the settingvalues used. The user determines the curve scaling with the Time multiplier setting.

The Minimum operate time setting defines the minimum operate time for the IDMTmode, that is, it is possible to limit the IDMT based operate time for not becomingtoo short. For example:



GUID-BCFE3F56-BFA8-4BCC-8215-30C089C80EAD V1 EN

Figure 417: Operate time curve based on IDMT characteristic with Minimumoperate time set to 0.5 second



GUID-90BAEB05-E8FB-4F8A-8F07-E110DD63FCCF V1 EN

Figure 418: Operate time curve based on IDMT characteristic with Minimumoperate time set to 1 second

11.3.1.1 Standard inverse-time characteristics for overvoltage protection

The operate times for the standard overvoltage IDMT curves are defined with thecoefficients A, B, C, D and E.

The inverse operate time can be calculated with the formula:



t sk A

BU U

UC

DE

=

⋅

×− >

>−

+

GUID-6E9DC0FE-7457-4317-9480-8CCC6D63AB35 V2 EN (Equation 93)

t [s] operate time in seconds

U measured voltage

U> the set value of Start value

k the set value of Time multiplier

Table 613: Curve coefficients for the standard overvoltage IDMT curves

Curve name A B C D E(17) Inverse Curve A 1 1 0 0 1

(18) Inverse Curve B 480 32 0.5 0.035 2

(19) Inverse Curve C 480 32 0.5 0.035 3



GUID-ACF4044C-052E-4CBD-8247-C6ABE3796FA6 V1 EN

Figure 419: Inverse curve A characteristic of overvoltage protection



GUID-F5E0E1C2-48C8-4DC7-A84B-174544C09142 V1 EN

Figure 420: Inverse curve B characteristic of overvoltage protection



GUID-A9898DB7-90A3-47F2-AEF9-45FF148CB679 V1 EN

Figure 421: Inverse curve C characteristic of overvoltage protection

11.3.1.2 User programmable inverse-time characteristics for overvoltageprotection

The user can define the curves by entering the parameters using the standard formula:



t sk A

BU U

UC

DE

=

⋅

×− >

>−

+

GUID-6E9DC0FE-7457-4317-9480-8CCC6D63AB35 V2 EN (Equation 94)

t[s] operate time in seconds

A the set value of Curve parameter A

B the set value of Curve parameter B

C the set value of Curve parameter C

D the set value of Curve parameter D

E the set value of Curve parameter E

U measured voltage

U> the set value of Start value


11.3.1.3 IDMT curve saturation of overvoltage protection

For the overvoltage IDMT mode of operation, the integration of the operate timedoes not start until the voltage exceeds the value of Start value. To cope withdiscontinuity characteristics of the curve, a specific parameter for saturating theequation to a fixed value is created. The Curve Sat Relative setting is the parameterand it is given in percents compared to Start value. For example, due to the curveequation B and C, the characteristics equation output is saturated in such a way thatwhen the input voltages are in the range of Start value to Curve Sat Relative inpercent over Start value, the equation uses Start value * (1.0 + Curve Sat Relative /100 ) for the measured voltage. Although, the curve A has no discontinuities whenthe ratio U/U> exceeds the unity, Curve Sat Relative is also set for it. The CurveSat Relative setting for curves A, B and C is 2.0 percent. However, it should benoted that the user must carefully calculate the curve characteristics concerning thediscontinuities in the curve when the programmable curve equation is used. Thus,the Curve Sat Relative parameter gives another degree of freedom to move theinverse curve on the voltage ratio axis and it effectively sets the maximum operatetime for the IDMT curve because for the voltage ratio values affecting by thissetting, the operation time is fixed, that is, the definite time, depending on theparameters but no longer the voltage.

11.3.2 IDMT curves for undervoltage protectionIn the inverse-time modes, the operate time depends on the momentary value of thevoltage, the lower the voltage, the faster the operate time. The operate timecalculation or integration starts immediately when the voltage goes below the setvalue of the Start value setting and the START output is activated.

The OPERATE output of the component is activated when the cumulative sum ofthe integrator calculating the undervoltage situation exceeds the value set by the



inverse-time mode. The set value depends on the selected curve type and thesetting values used. The user determines the curve scaling with the Time multipliersetting.

The Minimum operate time setting defines the minimum operate time possible forthe IDMT mode. For setting a value for this parameter, the user should carefullystudy the particular IDMT curve.

11.3.2.1 Standard inverse-time characteristics for undervoltage protection

The operate times for the standard undervoltage IDMT curves are defined with thecoefficients A, B, C, D and E.

The inverse operate time can be calculated with the formula:

t sk A

BU U

UC

DE

=

⋅

×< −

<−

+

GUID-4A433D56-D7FB-412E-B1AB-7FD43051EE79 V2 EN (Equation 95)

t [s] operate time in seconds

U measured voltage

U< the set value of the Start value setting

k the set value of the Time multiplier setting

Table 614: Curve coefficients for standard undervoltage IDMT curves

Curve name A B C D E(21) InverseCurve A

1 1 0 0 1

(22) InverseCurve B

480 32 0.5 0.055 2



GUID-35F40C3B-B483-40E6-9767-69C1536E3CBC V1 EN

Figure 422: : Inverse curve A characteristic of undervoltage protection



GUID-B55D0F5F-9265-4D9A-A7C0-E274AA3A6BB1 V1 EN

Figure 423: Inverse curve B characteristic of undervoltage protection

11.3.2.2 User-programmable inverse-time characteristics for undervoltageprotection

The user can define curves by entering parameters into the standard formula:



t sk A

BU U

UC

DE

=

⋅

×< −

<−

+

GUID-4A433D56-D7FB-412E-B1AB-7FD43051EE79 V2 EN (Equation 96)

t[s] operate time in seconds

A the set value of Curve parameter A

B the set value of Curve parameter B

C the set value of Curve parameter C

D the set value of Curve parameter D

E the set value of Curve parameter E

U measured voltage

U< the set value of Start value


11.3.2.3 IDMT curve saturation of undervoltage protection

For the undervoltage IDMT mode of operation, the integration of the operate timedoes not start until the voltage falls below the value of Start value. To cope withdiscontinuity characteristics of the curve, a specific parameter for saturating theequation to a fixed value is created. The Curve Sat Relative setting is the parameterand it is given in percents compared with Start value. For example, due to thecurve equation B, the characteristics equation output is saturated in such a way thatwhen input voltages are in the range from Start value to Curve Sat Relative inpercents under Start value, the equation uses Start value * (1.0 - Curve SatRelative / 100 ) for the measured voltage. Although, the curve A has nodiscontinuities when the ratio U/U> exceeds the unity, Curve Sat Relative is set forit as well. The Curve Sat Relative setting for curves A, B and C is 2.0 percent.However, it should be noted that the user must carefully calculate the curvecharacteristics concerning also discontinuities in the curve when the programmablecurve equation is used. Thus, the Curve Sat Relative parameter gives anotherdegree of freedom to move the inverse curve on the voltage ratio axis and iteffectively sets the maximum operate time for the IDMT curve because for thevoltage ratio values affecting by this setting, the operation time is fixed, that is, thedefinite time, depending on the parameters but no longer the voltage.

11.4 Frequency measurement and protection

All the function blocks that use frequency quantity as their input signal share thecommon features related to the frequency measurement algorithm. The frequencyestimation is done from one phase (phase-to-phase or phase voltage) or from thepositive phase sequence (PPS). The voltage groups with three-phase inputs use PPSas the source. The frequency measurement range is 0.6 xFn to 1.5 xFn. When thefrequency exceeds these limits, it is regarded as out of range and a minimum or



maximum value is held as the measured value respectively with appropriate qualityinformation. The frequency estimation requires 160 ms to stabilize after a badquality signal. Therefore, a delay of 160 ms is added to the transition from the badquality. The bad quality of the signal can be due to restrictions like:

• The source voltage is below 0.02 x Un at Fn.• The source voltage waveform is discontinuous.• The source voltage frequency rate of change exceeds 15 Hz/s (including

stepwise frequency changes).

When the bad signal quality is obtained, the nominal frequency value is shownwith appropriate quality information in the measurement view. The frequencyprotection functions are blocked when the quality is bad, thus the timers and thefunction outputs are reset. When the frequency is out of the function block’s settingrange but within the measurement range, the protection blocks are running.However, the OPERATE outputs are blocked until the frequency restores to a validrange.

11.5 Measurement modes

In many current or voltage dependent function blocks, there are four alternativemeasuring principles:

• RMS• DFT which is a numerically calculated fundamental component of the signal• Peak-to-peak• Peak-to-peak with peak backup

Consequently, the measurement mode can be selected according to the application.

In extreme cases, for example with high overcurrent or harmonic content, themeasurement modes function in a slightly different way. The operation accuracy isdefined with the frequency range of f/fn=0.95...1.05. In peak-to-peak and RMSmeasurement modes, the harmonics of the phase currents are not suppressed,whereas in the fundamental frequency measurement the suppression of harmonicsis at least -50 dB at the frequency range of f= n x fn, where n = 2, 3, 4, 5,...

RMSThe RMS measurement principle is selected with the Measurement mode settingusing the value "RMS". RMS consists of both AC and DC components. The ACcomponent is the effective mean value of the positive and negative peak values.RMS is used in applications where the effect of the DC component must be takeninto account.

RMS is calculated according to the formula:



IRMS i

i

n

nI=

=

∑1 2

1


n the number of samples in a calculation cycle

Ii the current sample value

DFTThe DFT measurement principle is selected with the Measurement mode settingusing the value "DFT". In the DFT mode, the fundamental frequency component ofthe measured signal is numerically calculated from the samples. In someapplications, for example, it can be difficult to accomplish sufficiently sensitivesettings and accurate operation of the low stage, which may be due to aconsiderable amount of harmonics on the primary side currents. In such a case, theoperation can be based solely on the fundamental frequency component of thecurrent. In addition, the DFT mode has slightly higher CT requirements than the peak-to-peak mode, if used with high and instantaneous stages.

Peak-to-peakThe peak-to-peak measurement principle is selected with the Measurement modesetting using the value "Peak-to-Peak". It is the fastest measurement mode, inwhich the measurement quantity is made by calculating the average from thepositive and negative peak values. The DC component is not included. Theretardation time is short. The damping of the harmonics is quite low and practicallydetermined by the characteristics of the anti-aliasing filter of the IED inputs.Consequently, this mode is usually used in conjunction with high and instantaneousstages, where the suppression of harmonics is not so important. In addition, the peak-to-peak mode allows considerable CT saturation without impairing theperformance of the operation.

Peak-to-peak with peak backupThe peak-to-peak with peak backup measurement principle is selected with theMeasurement mode setting using the value "P-to-P+backup". It is similar to the peak-to-peak mode, with the exception that it has been enhanced with the peak backup.In the peak-to-peak with peak backup mode, the function starts with twoconditions: the peak-to-peak value is above the set start current or the peak value isabove two times the set Start value. The peak backup is enabled only when thefunction is used in the DT mode in high and instantaneous stages for faster operation.



11.6 Calculated measurements

Calculated residual current and voltageThe residual current is calculated from the phase currents according to equation:

Io I I IA B C= − + +( )

GUID-B9280304-8AC0-40A5-8140-2F00C1F36A9E V1 EN (Equation 98)

The residual voltage is calculated from the phase-to-earth voltages when the VTconnection is selected as “Wye” with the equation:

Uo U U UA B C= + +( ) / 3

GUID-03909E83-8AA3-42FF-B088-F216BBB16839 V1 EN (Equation 99)

Sequence componentsThe phase-sequence current components are calculated from the phase currentsaccording to:

I I I IA B C0 3= + +( ) /

GUID-2319C34C-8CC3-400C-8409-7E68ACA4F435 V2 EN (Equation 100)

I I a I a IA B C12

3= + ⋅ + ⋅( ) /

GUID-02E717A9-A58F-41B3-8813-EB8CDB78CBF1 V2 EN (Equation 101)

I I a I a IA B C22

3= + ⋅ + ⋅( ) /

GUID-80F92D60-0425-4F1F-9B18-DB2DEF4C2407 V2 EN (Equation 102)

The phase-sequence voltage components are calculated from the phase-to-earthvoltages when VT connection is selected as “Wye” with the equations:

U U U UA B C0 3= + +( ) /

GUID-49CFB460-5B74-43A6-A72C-AAD3AF795716 V2 EN (Equation 103)

U U a U a UA B C12

3= + ⋅ + ⋅( ) /

GUID-7A6B6AAD-8DDC-4663-A72F-A3715BF3E56A V2 EN (Equation 104)

U U a U a UA B C22

3= + ⋅ + ⋅( ) /

GUID-6FAAFCC1-AF25-4A0A-8D9B-FC2FD0BCFB21 V1 EN (Equation 105)

When VT connection is selected as “Delta”, the positive and negative phasesequence voltage components are calculated from the phase-to-phase voltagesaccording to the equations:

U U a UAB BC12

3= − ⋅( ) /

GUID-70796339-C68A-4D4B-8C10-A966BD7F090C V2 EN (Equation 106)

U U a UAB BC2 3= − ⋅( ) /

GUID-C132C6CA-B5F9-4DC1-94AF-FF22D2F0F12A V2 EN (Equation 107)



The phase-to-earth voltages are calculated from the phase-to-phase voltages whenVT connection is selected as "Delta" according to the equations.

U U U UA AB CA= + −( )0 3/

GUID-8581E9AC-389C-40C2-8952-3C076E74BDEC V1 EN (Equation 108)

U U U UB BC AB= + −( )0 / 3

GUID-9EB6302C-2DB8-482F-AAC3-BB3857C6F100 V1 EN (Equation 109)

U U U UC CA BC= + −( )0 / 3

GUID-67B3ACF2-D8F5-4829-B97C-7E2F3158BF8E V1 EN (Equation 110)

If the U 0 channel is not valid, it is assumed to be zero.

The phase-to-phase voltages are calculated from the phase-to-earth voltages whenVT connection is selected as "Wye" according to the equations.

U U UAB A B= −

GUID-674F05D1-414A-4F76-B196-88441B7820B8 V1 EN (Equation 111)

U U UBC B C= −

GUID-9BA93C77-427D-4044-BD68-FEE4A3A2433E V1 EN (Equation 112)

U U UCA C A= −

GUID-DDD0C1F0-6934-4FB4-9F79-702440125979 V1 EN (Equation 113)



Section 12 Requirements for measurementtransformers

12.1 Current transformers

12.1.1 Current transformer requirements for non-directionalovercurrent protectionFor reliable and correct operation of the overcurrent protection, the CT has to bechosen carefully. The distortion of the secondary current of a saturated CT mayendanger the operation, selectivity, and co-ordination of protection. However,when the CT is correctly selected, a fast and reliable short circuit protection can beenabled.

The selection of a CT depends not only on the CT specifications but also on thenetwork fault current magnitude, desired protection objectives, and the actual CTburden. The protection settings of the IED should be defined in accordance withthe CT performance as well as other factors.

12.1.1.1 Current transformer accuracy class and accuracy limit factor

The rated accuracy limit factor (Fn) is the ratio of the rated accuracy limit primarycurrent to the rated primary current. For example, a protective current transformerof type 5P10 has the accuracy class 5P and the accuracy limit factor 10. Forprotective current transformers, the accuracy class is designed by the highestpermissible percentage composite error at the rated accuracy limit primary currentprescribed for the accuracy class concerned, followed by the letter "P" (meaningprotection).

Table 615: Limits of errors according to IEC 60044-1 for protective current transformers

Accuracy class Current error atrated primarycurrent (%)

Phase displacement at rated primarycurrent

Composite error atrated accuracy limitprimary current (%)minutes centiradians

5P ±1 ±60 ±1.8 5

10P ±3 - - 10

The accuracy classes 5P and 10P are both suitable for non-directional overcurrentprotection. The 5P class provides a better accuracy. This should be noted also ifthere are accuracy requirements for the metering functions (current metering,power metering, and so on) of the IED.

1MRS756887 G Section 12Requirements for measurement transformers


The CT accuracy primary limit current describes the highest fault currentmagnitude at which the CT fulfils the specified accuracy. Beyond this level, thesecondary current of the CT is distorted and it might have severe effects on theperformance of the protection IED.

In practise, the actual accuracy limit factor (Fa) differs from the rated accuracylimit factor (Fn) and is proportional to the ratio of the rated CT burden and theactual CT burden.

The actual accuracy limit factor is calculated using the formula:

F FS S

S Sa n

in n

in

≈ ×+

+

A071141 V1 EN

Fn the accuracy limit factor with the nominal external burden Sn

Sin the internal secondary burden of the CT

S the actual external burden

12.1.1.2 Non-directional overcurrent protection

The current transformer selectionNon-directional overcurrent protection does not set high requirements on theaccuracy class or on the actual accuracy limit factor (Fa) of the CTs. It is, however,recommended to select a CT with Fa of at least 20.

The nominal primary current I1n should be chosen in such a way that the thermaland dynamic strength of the current measuring input of the IED is not exceeded.This is always fulfilled when

I1n > Ikmax / 100,

Ikmax is the highest fault current.

The saturation of the CT protects the measuring circuit and the current input of theIED. For that reason, in practice, even a few times smaller nominal primary currentcan be used than given by the formula.

Recommended start current settingsIf Ikmin is the lowest primary current at which the highest set overcurrent stage is tooperate, the start current should be set using the formula:

Current start value < 0.7 x (Ikmin / I1n)

I1n is the nominal primary current of the CT.

Section 12 1MRS756887 GRequirements for measurement transformers


The factor 0.7 takes into account the protection IED inaccuracy, currenttransformer errors, and imperfections of the short circuit calculations.

The adequate performance of the CT should be checked when the setting of thehigh set stage overcurrent protection is defined. The operate time delay caused bythe CT saturation is typically small enough when the overcurrent setting isnoticeably lower than Fa.

When defining the setting values for the low set stages, the saturation of the CTdoes not need to be taken into account and the start current setting is simplyaccording to the formula.

Delay in operation caused by saturation of current transformersThe saturation of CT may cause a delayed IED operation. To ensure the timeselectivity, the delay must be taken into account when setting the operate times ofsuccessive IEDs.

With definite time mode of operation, the saturation of CT may cause a delay thatis as long as the time the constant of the DC component of the fault current, whenthe current is only slightly higher than the starting current. This depends on theaccuracy limit factor of the CT, on the remanence flux of the core of the CT, andon the operate time setting.

With inverse time mode of operation, the delay should always be considered asbeing as long as the time constant of the DC component.

With inverse time mode of operation and when the high-set stages are not used, theAC component of the fault current should not saturate the CT less than 20 times thestarting current. Otherwise, the inverse operation time can be further prolonged.Therefore, the accuracy limit factor Fa should be chosen using the formula:

Fa > 20*Current start value / I1n

The Current start value is the primary pickup current setting of the IED.

12.1.1.3 Example for non-directional overcurrent protection

The following figure describes a typical medium voltage feeder. The protection isimplemented as three-stage definite time non-directional overcurrent protection.

1MRS756887 G Section 12Requirements for measurement transformers


A071142 V1 EN

Figure 424: Example of three-stage overcurrent protection

The maximum three-phase fault current is 41.7 kA and the minimum three-phaseshort circuit current is 22.8 kA. The actual accuracy limit factor of the CT iscalculated to be 59.

The start current setting for low-set stage (3I>) is selected to be about twice thenominal current of the cable. The operate time is selected so that it is selective withthe next IED (not visible in the figure above). The settings for the high-set stageand instantaneous stage are defined also so that grading is ensured with thedownstream protection. In addition, the start current settings have to be defined sothat the IED operates with the minimum fault current and it does not operate withthe maximum load current. The settings for all three stages are as in the figure above.

For the application point of view, the suitable setting for instantaneous stage (I>>>)in this example is 3 500 A (5.83 x I2n). For the CT characteristics point of view, thecriteria given by the current transformer selection formula is fulfilled and also theIED setting is considerably below the Fa. In this application, the CT rated burdencould have been selected much lower than 10 VA for economical reasons.

Section 12 1MRS756887 GRequirements for measurement transformers


Section 13 IED physical connections

13.1 Protective earth connections

7

6

7

8

24

23

22

21

20

19

18

17

16

15

14

13

12

11

10

9

5

4

3

2

1

8

6

23

1

2

3

4

5

9

10

11

12

13

14

15

16

17

18

19

20

21

22

24

A070772 V1 EN

Figure 425: The protective earth screw is located between connectors X100and X110

The earth lead must be at least 6.0 mm2 and as short as possible.

13.2 Binary and analog connections

All binary and analog connections are described in the productspecific application manuals.

1MRS756887 G Section 13IED physical connections


13.3 Communication connections

The front communication connection is an RJ-45 type connector used mainly forconfiguration and setting.

For RED615, the rear communication module is mandatory due to the connectionneeded for the line-differential protection communication. If stationcommunication is needed for REF615, REM615, RET615 or REU615, an optionalrear communication module is required. Several optional communicationconnections are available.

• Galvanic RJ-45 Ethernet connection• Optical LC Ethernet connection• ST-type glass fibre serial connection• EIA-485 serial connection• EIA-232 serial connection

Never touch the end face of an optical fiber connector.

Always install dust caps on unplugged fiber connectors.

If contaminated, clean optical connectors only with fiber-opticcleaning products.

13.3.1 Ethernet RJ-45 front connectionThe IED is provided with an RJ-45 connector on the LHMI. The connector isintended for configuration and setting purposes. The interface on the PC side has tobe configured in a way that it obtains the IP address automatically. There is aDHCP server inside IED for the front interface only.

The events and setting values and all input data such as memorized values anddisturbance records can be read via the front communication port.

Only one of the possible clients can be used for parametrization at a time.

• PCM600• LHMI• WHMI

Section 13 1MRS756887 GIED physical connections


The default IP address of the IED through this port is 192.168.0.254.

The front port supports TCP/IP protocol. A standard Ethernet CAT 5 crossovercable is used with the front port.

The speed of the front connector interface is limited to 10 Mbps.

13.3.2 Ethernet rear connectionsThe Ethernet station bus communication module is provided with either galvanicRJ-45 connection or optical multimode LC type connection, depending on theproduct variant and the selected communication interface option. A shielded twisted-pair cable CAT 5e is used with the RJ-45 connector and an optical multi-modecable (≤2 km) with the LC type connector.

In addition, communication modules with multiple Ethernet connectors enable theforwarding of Ethernet traffic. The variants include an internal switch that handlesthe Ethernet traffic between an IED and a station bus. In this case, the usednetwork can be a ring or daisy-chain type of network topology. In loop typetopology, a self-healing Ethernet loop is closed by a managed switch supportingrapid spanning tree protocol. In daisy-chain type of topology, the network is bustype and it is either without switches, where the station bus starts from the stationclient, or with a switch to connect some devices and the IEDs of this product seriesto the same network.

Communication modules including Ethernet connectors X1, X2, and X3 can utilizethe third port for connecting any other device (for example, an SNTP server, that isvisible for the whole local subnet) to a station bus. In RED615, the first Ethernetport X16 is dedicated to the line differential communication and it cannot be usedfor station bus communication.

The IED's default IP address through rear Ethernet port is 192.168.2.10 with the TCP/IP protocol. The data transfer rate is 100 Mbps.

13.3.3 EIA-232 serial rear connectionThe EIA-232 connection follows the TIA/EIA-232 standard and is intended to beused with a point-to-point connection. The connection supports hardware flowcontrol (RTS, CTS, DTR, DSR), full-duplex and half-duplex communication.

13.3.4 EIA-485 serial rear connectionThe EIA-485 communication module follows the TIA/EIA-485 standard and isintended to be used in a daisy-chain bus wiring scheme with 2-wire half-duplex or 4-wire full-duplex, multi-point communication.



The maximum number of devices (nodes) connected to the buswhere the IED is used is 32, and the maximum length of the bus is1200 meters.

13.3.5 Line differential protection communication connectionThe protection communication port using dedicated link is provided with either asingle mode or a multimode connection with an LC type connector. The LCcommunication (X16/LD) is always the topmost in the communication module.

The port cannot be used with any other Ethernet communication network. Theinterface speed is 100 Mbps.

Use direct link. Switches, hubs or routers are not allowed betweenthe IEDs.

If galvanic pilot wire is used as protection communication link, the pilot wiremodem RPW600 is required. The protection communication link always requirestwo modems in a protection scheme, thus delivered in pairs of master (RPW600M)and follower (RPW600F) units. A single-mode fibre optic cable with dual LC typeconnectors is used to connect RED615 with RPW600 modem. The recommendedminimum length for this cable is 3 m.

Communication port X16/LD of RED615 is used both for directfibre optic link and connection with the pilot wire modem.

The RPW600 modem has a built-in 5 kVAC (RMS, 1 min) levelinsulation against earth potential in the pilot wire connection.

13.3.6 Optical ST serial rear connectionSerial communication can be used optionally through an optical connection eitherin loop or star topology. The connection idle state is light on or light off.

13.3.7 Communication interfaces and protocolsThe communication protocols supported depend on the optional rearcommunication module.



Table 616: Supported station communication interfaces and protocols

Interfaces/Protocols

Ethernet Serial100BASE-TX

RJ-45 100BASE-FX LC1) EIA-232/EIA-485 Fibre-optic ST

IEC 61850 - -

MODBUS RTU/ASCII

- -

MODBUS TCP/IP - -

DNP3 (serial) - -

DNP3 TCP/IP - -

IEC 60870-5-103 - -

= Supported

1) Not available for RED615

13.3.8 Rear communication modules

COM0001RJ-45

COM0002LC

COM0003RS-485+IRIG-B

COM0005RJ-45+ARC

COM0006LC+ARC

COM0007RS-485+IRIG-B+ARC

GUID-9942EA65-7B6F-4987-BD1A-9A88B0B222D6 V2 EN

Figure 426: Communication module options



COM0008 COM0010

IRIG-B

COM0012

IRIG-B+ARC

COM0013

IRIG-B+ARC

COM0014

LC+RS485+ RJ-45+RS485+ LC+RS485+

IRIG-B

RJ-45+RS485+

COM0011 COM0023

RJ-45+RS232/485+

RS485+ST+

IRIG-B

GUID-07821EE0-53E5-44A8-82BF-1C1D652DD21E V1 EN




COM00313xRJ-45

COM00322xLC+RJ-45+ST+ARC

COM00333xRJ-45+ST+ARC

COM0034LC+2xRJ-45+ST+ARC

GUID-AF5B9B14-A1F1-4EED-96AD-DA0665226860 V3 EN


Table 617: Station bus communication interfaces included in communication modules

Module ID RJ-45 LC EIA-485 EIA-232 STCOM0001 1 - - - -

COM0002 - 1 - - -

COM0003 - - 1 - -

COM0005 1 - - - -

COM0006 - 1 - - -

COM0007 - - 1 - -

COM00081) 2 - 1 - 1

COM00101) 2 - 1 - 1

COM0011 1 - 1 - -

COM0012 - 1 1 - -

COM0013 1 - 1 - -

COM0014 - 1 1 - -

COM0023 1 - 1 1 1

COM0031 3 - - - -




Module ID RJ-45 LC EIA-485 EIA-232 STCOM0032 1 2 - - 1

COM0033 3 - - - 1

COM0034 2 1 - - 1

1) Available only for RED615.

Table 618: LED descriptions for COM0001-COM0014

LED Connector Description1)

X1 X1 X1/LAN link status and activity (RJ-45 and LC)

RX1 X5 COM2 2-wire/4-wire receive activity

TX1 X5 COM2 2-wire/4-wire transmit activity

RX2 X5 COM1 2-wire receive activity

TX2 X5 COM1 2-wire transmit activity

I-B X5 IRIG-B signal activity

1) Depending on the COM module and jumper configuration

Table 619: LED descriptions for COM0008 and COM0010


X16 X16 X16/LD link status and activity

X1 X1 X1/LAN link status and activity

X2 X2 X2/LAN link status and activity

RX X5 COM1 2-wire receive activity/COM2 4-wire receive activity

TX X5 COM1 2-wire transmit activity/COM2 4-wire transmit activity

RX X5/X12 COM2 2-wire receive activity/COM2 4-wire receive activity

TX X5/X12 COM2 2-wire transmit activity/COM2 4-wire transmit activity


1) Depending on the jumper configuration

Table 620: LED descriptions for COM0023


FX X12 Not used by COM0023

X1 X1 LAN Link status and activity (RJ-45 and LC)

FL X12 Not used by COM0023

RX X6 COM1 2-wire / 4-wire receive activity

TX X6 COM1 2-wire / 4-wire transmit activity

RX X5 / X12 COM2 2-wire / 4-wire or fiber-optic receive activity

TX X5 / X12 COM2 2-wire / 4-wire or fiber-optic transmit activity


1) Depending on the jumper configuration



Table 621: LED descriptions for COM0031-COM0034

LED Connector DescriptionX1 X1 X1/LAN1 link status and activity

X2 X2 X2/LAN2 link status and activity

X3 X3 X3/LAN3 link status and activity

RX X9 COM1 fiber-optic receive activity

TX X9 COM1 fiber-optic transmit activity

13.3.8.1 COM0001-COM0014 jumper locations and connections

X4X6X5

X8X9

X7

1 2 3

A070893 V3 EN

Figure 429: Jumper connectors on communication module



Table 622: 2-wire EIA-485 jumper connectors

Group Jumper connection Description NotesX4 1-2 A+ bias enabled COM2

2-wire connection2-3 A+ bias disabled

X5 1-2 B- bias enabled

2-3 B- bias disabled

X6 1-2 Bus terminationenabled

2-3 Bus terminationdisabled

X7 1-2 B- bias enabled COM12-wire connection

2-3 B- bias disabled

X8 1-2 A+ bias enabled

2-3 A+ bias disabled

X9 1-2 Bus terminationenabled

2-3 Bus terminationdisabled

The bus is to be biased at one end to ensure fail-safe operation, which can be doneusing the pull-up and pull-down resistors on the communication module. In 4-wireconnection the pull-up and pull-down resistors are selected by setting jumpers X4,X5, X7 and X8 to enabled position. The bus termination is selected by settingjumpers X6 and X9 to enabled position.

The jumpers have been set to no termination and no biasing as default.

Table 623: 4-wire EIA-485 jumper connectors for COM2

Group Jumper connection Description Notes

X41-2 A+ bias enabled

COM24-wire TX channel

2-3 A+ bias disabled 1)

X51-2 B- bias enabled

2-3 B- bias disabled1)

X6

1-2 Bus terminationenabled

2-3 Bus terminationdisabled1)





X71-2 B- bias enabled

COM24-wire RX channel

2-3 B- bias disabled1)

X81-2 A+ bias enabled

2-3 A+ bias disabled1)

X9

1-2 Bus terminationenabled

2-3 Bus terminationdisabled1)

1) Default setting

It is recommended to enable biasing only at one end of the bus.

Termination is enabled at each end of the bus.

It is recommended to ground the signal directly to earth from onenode and through capacitor from other nodes.

The optional communication modules include support for EIA-485 serialcommunication (X5 connector). Depending on the configuration, thecommunication modules can host either two 2-wire-ports or one 4-wire-port.

The two 2-wire ports are called COM1 and COM2. Alternatively, if there is onlyone 4-wire port configured, the port is called COM2. The fibre-optic ST connectionuses the COM1 port.

Table 624: EIA-485 connections for COM0001-COM0014

Pin 2-wire mode 4-wire mode10 COM1 A/+ COM2 Rx/+

9 B/- Rx/-

8 COM2 A/+ Tx/+

7 B/- Tx/-

6 AGND (isolated ground)

5 IRIG-B +

4 IRIG-B -

3 -

2 GNDC (case via capacitor)

1 GND (case)



13.3.8.2 COM0023 jumper locations and connections

The optional communication module supports EIA-232/EIA-485 serialcommunication (X6 connector), EIA-485 serial communication (X5 connector) andoptical ST serial communication (X12 connector).

Two independent communication ports are supported. The two 2-wire-ports arecalled COM1 and COM2. Alternatively, if only one 4-wire-port is configured, theport is called COM2. The fibre-optic ST connection uses the COM1 port.

Table 625: Configuration options of the two independent communication ports

COM1 connector X6 COM2 connector X5 or X12EIA-232 Optical ST (X12)

EIA-485 2-wire EIA-485 2-wire (X5)

EIA-485 4-wire EIA-485 4-wire (X5)



6

X2

6

X8

X1

1

X1

9

X9

X5

X7

X2

1

X6

X2

0

1

2

3

1

2

3

X1

7

X1

8

X1

6

X15

X14

X13

1 2 3

X24

1 2 3

X3X25

12

3 5

4

3

2

1

X2

7

X2

83

2

1

GUID-D4044F6B-2DA8-4C14-A491-4772BA108292 V1 EN

Figure 430: Jumper connections on communication module COM0023revisions A-F



1 2

3

1 2

3

X24X3

X5

1 2

3

1 2 3

X6

X21 X7

X20 X9

X19

X11

X8

X16 X18

X27

X13

X26

3 2

1

X14X15

X28

X17

3 2

1

GUID-1E542C3A-F6E9-4F94-BEFD-EA3FEEC65FC8 V1 EN

Figure 431: Jumper connections on communication module COM0023 revisionG

COM1 port connection type can be either EIA-232 or EIA-485. Type is selected bysetting jumpers X19, X20, X21, X26.

The jumpers are set to EIA-232 by default.

Table 626: EIA-232 and EIA-485 jumper connectors for COM1

Group Jumper connection DescriptionX19 1-2

2-3EIA-485EIA-232

X20 1-22-3

EIA-485EIA-232

X21 1-22-3

EIA-485EIA-232

X26 1-22-3

EIA-485EIA-232



To ensure fail-safe operation, the bus is to be biased at one end using the pull-upand pull-down resistors on the communication module. In the 4-wire connection,the pull-up and pull-down resistors are selected by setting jumpers X5, X6, X8, X9to enabled position. The bus termination is selected by setting jumpers X7, X11 toenabled position.



Group Jumper connection Description NotesX5 1-2

2-3A+ bias enabledA+ bias disabled1)

COM1Rear connector X62-wire connection

X6 1-22-3

B- bias enabledB- bias disabled1)

X7 1-22-3

Bus terminationenabledBus terminationdisabled1)

1) Default setting

Table 628: 4–wire EIA-485 jumper connectors for COM1


2-3A+ bias enabledA+ bias disabled1)

COM1Rear connector X64-wire TX channel

X6 1-22-3


X7 1-22-3


X9 1-22-3

A+ bias enabledA+ bias disabled1)

4-wire RX channel

X8 1-22-3


X11 1-22-3


1) Default setting

COM2 port connection can be either EIA-485 or optical ST. Connection type isselected by setting jumpers X27 and X28.

Table 629: COM2 serial connection X5 EIA-485/ X12 Optical ST


2-3EIA-485Optical ST

X28 1-22-3

EIA-485Optical ST





2-3A+ bias enabledA+ bias disabled

X14 1-22-3

B- bias enabledB- bias disabled

X15 1-22-3

Bus termination enabledBus termination disabled



2-3A+ bias enabledA+ bias disabled


X14 1-22-3


X15 1-22-3

Bus terminationenabledBus terminationdisabled

X16 1-22-3

Bus terminationenabledBus terminationdisabled

4-wire RX channelX17 1-22-3

A+ bias enabledA+ bias disabled

X18 1-22-3


Table 632: X12 Optical ST connection


2-3Star topologyLoop topology

X24 1-22-3

Idle state = Light onIdle state = Light off

Table 633: EIA-232 connections for COM0023 (X6)

Pin EIA-2321 DCD

2 RxD

3 TxD

4 DTR

5 AGND

6 -

7 RTS

8 CTS




Pin 2-wire mode 4-wire mode1 - Rx/+

6 - Rx/-

7 B/- Tx/-

8 A/+ Tx/+


Pin 2-wire mode 4-wire mode9 - Rx/+

8 - Rx/-

7 A/+ Tx/+

6 B/- Tx/-


4 IRIG-B +

3 IRIG-B -

2 -

1 GND (case)

13.3.8.3 COM0008 and COM0010 jumper locations and connections

The EIA-485 communication module follows the TIA/EIA-485 standard and isintended to be used in a daisy-chain bus wiring scheme with 2-wire or 4-wire, half-duplex, multi-point communication. Serial communication can be also usedthrough optical connection which is used either in loop or star topology.

Two parallel 2-wire serial communication channels can be used at the same time.Also optical serial connector can be used in parallel with one 2-wire or 4-wireserial channel.

The maximum number of devices (nodes) connected to the buswhere the IED is being used is 32, and the maximum length of thebus is 1200 meters.



X8

X9

X7

X3

X6

X5

X15

X24

1 2 3

X1

6

3

2

1

1 2 3

GUID-FDC31D60-8F9F-4D2A-A1A2-F0E57553C06B V1 EN

Figure 432: Jumper connectors on communication module

Table 636: 2-wire EIA-485 jumper connectors


X3

1-2 A+ Bias enabled COM12-wire connection

2-3 A+ Bias Disabled

X5

1-2 B- Bias enabled

2-3 B- Bias Disabled

X6

1-2Bus terminationenabled

2-3Bus terminationdisabled

X7

1-2 B- Bias enabled COM22-wire connection


X8

1-2 A+ Bias enabled


X9





The bus is to be biased at one end to ensure fail-safe operation, which can be doneusing the pull-up and pull-down resistors on the communication module. In 4-wireconnection the pull-up and pull-down resistors are selected by setting jumpers X3,X5, X7 and X8 to enabled position. The bus termination is selected by settingjumpers X6 and X9 to enabled position.




X3

1-2 A+ Bias enabled



X5

1-2 B- Bias enabled


X6



X7

1-2 B- Bias enabled

COM24-wire RX channel


X8

1-2 A+ Bias enabled


X9



Table 638: Jumper connectors for COM1 serial connection type

Group Jumper connection DescriptionX16 1-2 EIA-485 selected for COM1

2-3 FO_UART selected for COM1

X15 1-2 Star topology selected forFO_UART

2-3 Loop topology selected forFO_UART

X24 1-2 FO_UART channel idle state:Light on

2-3 FO_UART channel idle state:Light off

It is recommended to enable biasing only at one end of the bus.



Termination is enabled at each end of the bus

It is recommended to ground the signal directly to earth from onenode and through capacitor from other nodes.

The optional communication modules include support for EIA-485 serialcommunication (X5 connector). Depending on the configuration thecommunication modules can host either two 2-wire ports or one 4-wire port.

The two 2-wire ports are called as COM1 and COM2. Alternatively, if there is onlyone 4-wire port configured, the port is called COM2. The fibre-optic ST connectionuses the COM1 port.

Table 639: EIA-485 connections for COM0008 and COM0010

Pin 2-wire mode 4-wire mode9 COM1 A/+ COM2 Rx/+

8 B/- Rx/-

7 COM2 A/+ Tx/+

6 B/- Tx/-


4 IRIG-B +

3 IRIG-B -

2 GNDC (case via capasitor)

1 GND (case)

13.3.8.4 COM0032-COM0034 jumper locations and connections

The optional communication modules include support for optical ST serialcommunication (X9 connector). The fibre-optic ST connection uses the COM1 port.



X15 X24321

321

GUID-CA481BBF-C1C9-451D-BC18-19EC49B8A3A3 V1 EN

Figure 433: Jumper connections on communication module COM0032



1X15

3

X2412

32

GUID-4CAF22E5-1491-44EF-BFC7-45017DED68F4 V1 EN




3

1 X2421

32

X15

GUID-E54674FD-2E7F-4742-90AB-505772A0CFF4 V1 EN


Table 640: X9 Optical ST jumper connectors


2-3Star topologyLoop topology

X24 1-22-3

Idle state = Light onIdle state = Light off

13.3.9 Recommended third-party industrial Ethernet switches• RuggedCom RS900• RuggedCom RS1600• RuggedCom RSG2100



Section 14 Technical data

Table 641: Dimensions

Description Value Width frame 177 mm

case 164 mm

Height frame 177 mm (4U)

case 160 mm

Depth 201 mm (153 + 48 mm)

Weight complete IED 4.1 kg

plug-in unit only 2.1 kg

Table 642: Power supply

Description Type 1 Type 2Uauxnominal 100, 110, 120, 220, 240 V AC,

50 and 60 Hz24, 30, 48, 60 V DC

48, 60, 110, 125, 220, 250 V DC

Maximum interruption timein the auxiliary DC voltagewithout resetting the IED

50 ms at Unrated

Uauxvariation 38...110% of Un (38...264 V AC) 50...120% of Un (12...72 V DC)

80...120% of Un (38.4...300 V DC)

Start-up threshold 19.2 V DC (24 V DC * 80%)

Burden of auxiliary voltagesupply under quiescent (Pq)/operating condition

DC < 12.0 W (nominal)/< 18.0 W(max)AC< 16.0 W (nominal)/< 21.0W(max)

DC < 12.0 W (nominal)/< 18.0 W(max)

Ripple in the DC auxiliaryvoltage

Max 15% of the DC value (at frequency of 100 Hz)

Fuse type T4A/250 V

1MRS756887 G Section 14Technical data


Table 643: Energizing inputs

Description ValueRated frequency 50/60 Hz

Current inputs Rated current, In 0.2/1 A1)2) 1/5 A3)

Thermal withstand capability:

• Continuously 4 A 20 A

• For 1 s 100 A 500 A

Dynamic current withstand:

• Half-wave value 250 A 1250 A

Input impedance <100 mΩ <20 mΩ

Voltage inputs Rated voltage 60...210 V AC

Voltage withstand:

• Continuous 240 V AC

• For 10 s 360 V AC

Burden at rated voltage <0.05 VA

1) Ordering option for residual current input2) Not available for RET615 and REU6153) Residual current and/or phase current

Table 644: Energizing inputs

Description ValueCurrent sensor input Rated current voltage

(in secondary side)75 mV...2812.5 mV1)

Continuous voltagewithstand

125 V

Input impedance at50/60 Hz

2-3 MOhm2)

Voltage sensor input Rated voltage 6 kV...30 kV3)

Continuous voltagewithstand

50 V

Input impedance at50/60 Hz

3 MOhm

1) Equals the current range of 40A - 1250A with a 80A, 3mV/Hz Rogowski2) Depending on the used nominal current (hardware gain)3) This range is covered (up to 2*rated) with sensor division ratio of 10 000 : 1

Section 14 1MRS756887 GTechnical data


Table 645: Binary inputs

Description ValueOperating range ±20% of the rated voltage

Rated voltage 24...250 V DC

Current drain 1.6...1.9 mA

Power consumption 31.0...570.0 mW

Threshold voltage 18...176 V DC

Reaction time 3 ms

Table 646: RTD/mA inputs

Description ValueRTD inputs Supported RTD

sensors100 Ω platinum250 Ω platinum100 Ω nickel120 Ω nickel250 Ω nickel10 Ω copper

TCR 0.00385 (DIN 43760)TCR 0.00385TCR 0.00618 (DIN 43760)TCR 0.00618TCR 0.00618TCR 0.00427

Supportedresistance range 0...2 kΩ

Maximum leadresistance (three-wiremeasurement) 25 Ω per lead

Isolation 2 kV (inputs to protective earth)

Response time <4 s

RTD/resistancesensing current Maximum 0.33 mA rms

Operationaccuracy

Resistance Temperature

± 2.0% or ±1 Ω ±1°C10 Ω copper: ±2°C

mA inputs Supportedcurrent range 0…20 mA

Current inputimpedance 44 Ω ± 0.1%

Operationaccuracy ±0.5% or ±0.01 mA

Table 647: Signal output X100: SO1

Description ValueRated voltage 250 V AC/DC

Continuous contact carry 5 A

Make and carry for 3.0 s 15 A


Breaking capacity when the control-circuit timeconstant L/R<40 ms

1 A/0.25 A/0.15 A

Minimum contact load 100 mA at 24 V AC/DC



Table 648: Signal outputs and IRF output




Make and carry 0.5 s 15 A

Breaking capacity when the control-circuit timeconstant L/R<40 ms, at 48/110/220 V DC

1 A/0.25 A/0.15 A


Table 649: Double-pole power output relays with TCS function





Breaking capacity when the control-circuit timeconstant L/R<40 ms, at 48/110/220 V DC (twocontacts connected in series)

5 A/3 A/1 A


Trip-circuit supervision (TCS):

• Control voltage range 20...250 V AC/DC

• Current drain through the supervision circuit ~1.5 mA

• Minimum voltage over the TCS contact 20 V AC/DC (15...20 V)

Table 650: Single-pole power output relays


Continuous contact carry 8A



Breaking capacity when the control-circuit timeconstant L/R<40 ms, at 48/110/220 V DC

5 A/3 A/1 A




Table 651: Ethernet interfaces

Ethernet interface Protocol Cable Data transfer rateFront TCP/IP

protocolStandard Ethernet CAT 5 cable with RJ-45connector

10 MBits/s

Rear TCP/IPprotocol

Shielded twisted pair CAT 5e cable withRJ-45 connector or fibre-optic cable with LCconnector

100 MBits/s

Table 652: Serial rear interface

Type Counter connectorSerial port (X5) 10-pin counter connector Weidmüller BL

3.5/10/180F AU OR BEDRor9-pin counter connector Weidmüller BL3.5/9/180F AU OR BEDR1)

Serial port (X16) 9-pin D-sub connector DE-9

Serial port (X12) Optical ST-connector

1) Depending on the optional communication module

Table 653: Fibre-optic communication link

Connector Fibre type Wave length Max. distance Permitted path attenuation1)

LC MM 62.5/125 or50/125 μm glassfibre core

1300 nm 2 km <8 dB

ST MM 62.5/125 or50/125 μm glassfibre core

820-900 nm 1 km <11 dB

1) Maximum allowed attenuation caused by connectors and cable together

Table 654: Fibre-optic protection communication link available in RED615

Connector Fibre type Wave length Max. distance Permitted path attenuation1)

LC MM 62.5/125 or50/125 μm

1300 nm 2 km < 8 dB

LC SM 9/125 μm2) 1300 nm 20 km < 8 dB

1) Maximum allowed attenuation caused by connectors and cable altogether2) Use single-mode fibre with recommended minimum length of 3 m to connect RED615 to the pilot

wire modem RPW600.

Table 655: IRIG-B

Description ValueIRIG time code format B004, B0051)

Isolation 500V 1 min.

Modulation Unmodulated




Description ValueLogic level TTL Level

Current consumption 2...4 mA

Power consumption 10...20 mW

1) According to 200-04 IRIG -standard

Table 656: Lens sensor and optical fibre for arc protection

Description ValueFibre-optic cable including lens 1.5 m, 3.0 m or 5.0 m

Normal service temperature range of the lens -40...+100°C

Maximum service temperature range of the lens,max 1 h

+140°C

Minimum permissible bending radius of theconnection fibre

100 mm

Table 657: Degree of protection of flush-mounted IED

Description ValueFront side IP 54

Rear side, connection terminals IP 20

Table 658: Environmental conditions

Description ValueOperating temperature range -25...+55ºC (continuous)

Short-time service temperature range • REF615, REM615 and RET615:-40...+85ºC (<16 h)1)2)

• RED615: -40...+70ºC (<16 h)1)2)

Relative humidity <93%, non-condensing

Atmospheric pressure 86...106 kPa

Altitude Up to 2000 m

Transport and storage temperature range -40...+85ºC

1) Degradation in MTBF and HMI performance outside the temperature range of -25...+55 ºC2) For IEDs with an LC communication interface the maximum operating temperature is +70 ºC



Section 15 IED and functionality tests

Table 659: Electromagnetic compatibility tests

Description Type test value Reference1 MHz/100 kHz burstdisturbance test:

IEC 61000-4-18IEC 60255-22-1, class III

• Common mode 2.5 kV

• Differential mode 1 kV

Electrostatic discharge test: IEC 61000-4-2IEC 60255-22-2

• Contact discharge 8 kV (IED) 6 kV (HMI)

• Air discharge 15 kV (IED) 8 kV (HMI)

Radio frequency interferencetests:

• Conducted, commonmode 10 V (rms)

f=150 kHz-80 MHzIEC 61000-4-6IEC 60255-22-6, class III

• Radiated, amplitude-modulated 10 V/m (rms)

f=80-3000 MHzIEC 61000-4-3IEC 60255-22-3, class III

Fast transient disturbance tests:

• Communication port 2 kV IEC 61000-4-4IEC 60255-22-4, level 3

• Remaining port 4 kV IEC 61000-4-4IEC 60255-22-4, level 4

Surge immunity test: IEC 61000-4-5IEC 60255-22-5, level 4/3

• Binary inputs 4 kV, line-to-earth2 kV, line-to-line

• Communication 2 kV, line-to-earth

• Other ports 4 kV, line-to-earth2 kV, line-to-line

Power frequency (50 Hz)magnetic field:

IEC 61000-4-8, level 5

• Continuous• 1s short duration 100 A/m

1000 A/m

Voltage dips and shortinterruptions

100%/100 ms IEC 61000-4-11

Power frequency immunity test:

• Common mode 30 V rms continuous300 V rms 1 s

IEC 61000-4-16IEC 60255-22-7, level 4/3


1MRS756887 G Section 15IED and functionality tests


Description Type test value Reference• Differential mode 15 Hz-150 kHz

1 V-10 V

Emission tests: EN 55011CISPR 11, Group 1, Class A

• Conducted, RF-emission(mains terminal)

0.15-0.50 MHz < 79 dB(µV) quasi peak< 66 dB(µV) average

0.5-30 MHz < 73 dB(µV) quasi peak< 60 dB(µV) average

• Radiated, RF-emission

30-230 MHz < 50 dB(µV/m) quasi peak,measured at 3 m distance

230-1000 MHz < 57 dB(µV/m) quasi peak,measured at 3 m distance

Table 660: Insulation tests

Description Type test value ReferenceDielectric tests 2 kV, 50 Hz, 1 min

500 V, 50 Hz, 1 min,communication

IEC 60255-5 andIEC 60255-27

Impulse voltage test 5 kV, 1.2/50 μs, 0.5 J1 kV, 1.2/50 μs, 0.5 J,communication

IEC 60255-5 andIEC 60255-27

Insulation resistancemeasurements

>100 MΏ, 500 V DC IEC 60255-5 andIEC 60255-27

Protective bonding resistance <0.1 Ώ, 4 A, 60 s IEC 60255-27

Table 661: Mechanical tests

Description Reference RequirementVibration tests (sinusoidal) IEC 60068-2-6 (test Fc)

IEC 60255-21-1Class 2

Shock and bump test IEC 60068-2-27 (test Ea shock)IEC 60068-2-29 (test Eb bump)IEC 60255-21-2

Class 2

Seismic test IEC 60255-21-3 Class 2

Section 15 1MRS756887 GIED and functionality tests


Table 662: Environmental tests

Description Type test value ReferenceDry heat test • 96 h at +55ºC

• 16 h at +85ºC1)2)IEC 60068-2-2

Dry cold test • 96 h at -25ºC• 16 h at -40ºC

IEC 60068-2-1

Damp heat test • 6 cycles (12 h + 12 h) at+25°C…+55°C, humidity>93%

IEC 60068-2-30

Change of temperature test • 5 cycles (3 h + 3 h)at -25°C...+55°C

IEC60068-2-14

Storage test • 96 h at -40ºC• 96 h at +85ºC

IEC 60068-2-1IEC 60068-2-2

1) For IEDs with an LC communication interface the maximum operating temperature is +70oC2) For RED615 +70oC, 16 h

Table 663: Product safety

Description ReferenceLV directive 2006/95/EC

Standard EN 60255-27 (2005)EN 60255-1 (2009)

Table 664: EMC compliance

Description ReferenceEMC directive 2004/108/EC

Standard EN 50263 (2000)EN 60255-26 (2007)

1MRS756887 G Section 15IED and functionality tests


Section 16 Applicable standards and regulations

EN 50263

EN 60255-26

EN 60255-27

EMC council directive 2004/108/EC

EU directive 2002/96/EC/175

IEC 60255

Low-voltage directive 2006/95/EC

1MRS756887 G Section 16Applicable standards and regulations


Section 17 Glossary

ACT 1. Application Configuration tool in PCM6002. Trip status in IEC 61850

AIM Analog input moduleCAT 5 A twisted pair cable type designed for high signal

integrityCAT 5e An enhanced version of CAT 5 that adds specifications

for far end crosstalkCB Circuit breakerCBB Cycle building blockCPU Central processing unitCT Current transformerCTS Clear to sendDANP Doubly attached node with PRPDC 1. Direct current

2. Double commandDCD Data carrier detectDFT Discrete Fourier transformDHCP Dynamic Host Configuration ProtocolDNP3 A distributed network protocol originally developed by

Westronic. The DNP3 Users Group has the ownershipof the protocol and assumes responsibility for itsevolution.

DPC Double-point controlDSR Data set readyDT Definite timeDTR Data terminal readyEEPROM Electrically erasable programmable read-only memoryEIA-232 Serial communication standard according to

Electronics Industries AssociationEIA-485 Serial communication standard according to

Electronics Industries AssociationEMC Electromagnetic compatibility

1MRS756887 G Section 17Glossary


Ethernet A standard for connecting a family of frame-basedcomputer networking technologies into a LAN

FIFO First in, first outFLC Full load currentFPGA Field-programmable gate arrayGOOSE Generic Object-Oriented Substation EventGPS Global Positioning SystemHMI Human-machine interfaceHSR High-availability seamless redundancyHW HardwareIDMT Inverse definite minimum timeIEC International Electrotechnical CommissionIEC 60870-5-103 1. Communication standard for protective equipment

2. A serial master/slave protocol for point-to-pointcommunication

IEC 61850 International standard for substation communicationand modeling

IEC 61850-8-1 A communication protocol based on the IEC 61850standard series

IED Intelligent electronic deviceIET600 Integrated Engineering Toolbox in PCM600IP Internet protocolIP address A set of four numbers between 0 and 255, separated

by periods. Each server connected to the Internet isassigned a unique IP address that specifies thelocation for the TCP/IP protocol.

IRIG-B Inter-Range Instrumentation Group's time code format BLAN Local area networkLC Connector type for glass fibre cableLCD Liquid crystal displayLED Light-emitting diodeLHMI Local human-machine interfaceModbus A serial communication protocol developed by the

Modicon company in 1979. Originally used forcommunication in PLCs and RTU devices.

MV Medium voltagePC 1. Personal computer

Section 17 1MRS756887 GGlossary


2. PolycarbonatePCM600 Protection and Control IED ManagerPeak-to-peak 1. The amplitude of a waveform between its maximum

positive value and its maximum negative value2. A measurement principle where the measurementquantity is made by calculating the average from thepositive and negative peak values without including theDC component. The peak-to-peak mode allowsconsiderable CT saturation without impairing theperformance of the operation.

Peak-to-peak withpeak backup

A measurement principle similar to the peak-to-peakmode but with the function starting on two conditions:the peak-to-peak value is above the set start current orthe peak value is above two times the set start value

PLC Programmable logic controllerPPS Pulse per secondPRP Parallel redundancy protocolRAM Random access memoryRCA Also known as MTA or base angle. Characteristic angle.RED615 Line differential protection and control IEDREF615 Feeder protection and control IEDREM615 Motor protection and control IEDRET615 Transformer protection and control IEDRI Ring IndicatorRJ-45 Galvanic connector typeRMS Root-mean-square (value)ROM Read-only memoryRSTP Rapid spanning tree protocolRTC Real-time clockRTD Resistance temperature detectorRTS Ready to sendRx Receive/ReceivedSAN Singly attached nodeSBO Select-before-operateSCL XML-based substation description configuration

language defined by IEC 61850Single-linediagram

Simplified notation for representing a three-phasepower system. Instead of representing each of three

1MRS756887 G Section 17Glossary


phases with a separate line or terminal, only oneconductor is represented.

SLD Single-line diagramSMT Signal Matrix tool in PCM600SNTP Simple Network Time ProtocolSOTF Switch on to faultST Connector type for glass fibre cableSW SoftwareTCP/IP Transmission Control Protocol/Internet ProtocolTCS Trip-circuit supervisionTx Transmit/TransmittedUTC Coordinated universal timeVT Voltage transformerWAN Wide area networkWHMI Web human-machine interface

Section 17 1MRS756887 GGlossary


Contact us

ABB OyMedium Voltage Products,Distribution AutomationP.O. Box 699FI-65101 VAASA, FinlandPhone +358 10 22 11Fax +358 10 22 41094

ABB LimitedDistribution AutomationManejaVadodara 390013, IndiaPhone +91 265 2604032Fax +91 265 2638922

www.abb.com/substationautomation

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